0000922224 ppl:LouisvilleGasAndElectricCoMember ~~ppl:GasRatesMember ppl:KentuckyPublicServiceCommissionMember 2018-09-01 2018-09-30~~us-gaap:FairValueInputsLevel1Member us-gaap:FairValueMeasurementsRecurringMember 2020-03-31



UNITED STATES SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549

	FORM		10-Q

☒	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT
	OF 1934 for the quarterly period ended	~~September 30, 2019~~March 31, 2020
OR
☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT
	OF 1934 for the transition period from	_________ to ___________



Commission File Number	Registrant; State of Incorporation; Address and Telephone Number				IRS Employer Identification No.

1-11459	PPL Corporation				23-2758192
	(Exact name of Registrant as specified in its charter)
	Pennsylvania
	Two North Ninth Street
	Allentown,		PA	18101-1179
	(610)	774-5151

1-905	PPL Electric Utilities Corporation				23-0959590
	(Exact name of Registrant as specified in its charter)
	Pennsylvania
	Two North Ninth Street
	Allentown,		PA	18101-1179
	(610)	774-5151

333-173665	LG&E and KU Energy LLC				20-0523163
	(Exact name of Registrant as specified in its charter)
	Kentucky
	220 West Main Street
	Louisville,		KY	40202-1377
	(502)	627-2000

1-2893	Louisville Gas and Electric Company				61-0264150
	(Exact name of Registrant as specified in its charter)
	Kentucky
	220 West Main Street
	Louisville,		KY	40202-1377
	(502)	627-2000

1-3464	Kentucky Utilities Company				61-0247570
	(Exact name of Registrant as specified in its charter)
	Kentucky and Virginia
	One Quality Street
	Lexington,		KY	40507-1462
	(502)	627-2000

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Securities registered pursuant to Section 12(b) of the Act:



Title of each class	Trading Symbol:	Name of each exchange on which registered
Common Stock of PPL Corporation	PPL	New York Stock Exchange

Junior Subordinated Notes of PPL Capital Funding, Inc.
2007 Series A due 2067	PPL/67	New York Stock Exchange
2013 Series B due 2073	PPX	New York Stock Exchange

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.



PPL Corporation	Yes	☒	No	☐
PPL Electric Utilities Corporation	Yes	☒	No	☐
LG&E and KU Energy LLC	Yes	☒	No	☐
Louisville Gas and Electric Company	Yes	☒	No	☐
Kentucky Utilities Company	Yes	☒	No	☐

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit such files).



PPL Corporation	Yes	☒	No	☐
PPL Electric Utilities Corporation	Yes	☒	No	☐
LG&E and KU Energy LLC	Yes	☒	No	☐
Louisville Gas and Electric Company	Yes	☒	No	☐
Kentucky Utilities Company	Yes	☒	No	☐

Indicate by check mark whether the registrants are large accelerated filers, accelerated filers, non-accelerated filers, smaller reporting companies or emerging growth companies. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company" and "emerging growth company" in Rule 12b-2 of the Exchange Act.



	Large accelerated filer	Accelerated filer	Non-accelerated filer	Smaller reporting company	Emerging growth company
PPL Corporation	☒	☐	☐	☐	☐
PPL Electric Utilities Corporation	☐	☐	☒	☐	☐
LG&E and KU Energy LLC	☐	☐	☒	☐	☐
Louisville Gas and Electric Company	☐	☐	☒	☐	☐
Kentucky Utilities Company	☐	☐	☒	☐	☐

If emerging growth companies, indicate by check mark if the registrants have elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.



PPL Corporation	☐
PPL Electric Utilities Corporation	☐
LG&E and KU Energy LLC	☐
Louisville Gas and Electric Company	☐
Kentucky Utilities Company	☐

Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act).



PPL Corporation	Yes	☐	No	☒
PPL Electric Utilities Corporation	Yes	☐	No	☒
LG&E and KU Energy LLC	Yes	☐	No	☒
Louisville Gas and Electric Company	Yes	☐	No	☒
Kentucky Utilities Company	Yes	☐	No	☒

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Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of the latest practicable date.


PPL Corporation	Common stock, $0.01 par value, ~~723,033,043~~768,763,491 shares outstanding at ~~October 31, 2019.~~April 30, 2020.


PPL Electric Utilities Corporation	Common stock, no par value, 66,368,056 shares outstanding and all held by PPL Corporation at ~~October 31, 2019.~~April 30, 2020.


LG&E and KU Energy LLC	PPL Corporation directly holds all of the membership interests in LG&E and KU Energy LLC.


Louisville Gas and Electric Company	Common stock, no par value, 21,294,223 shares outstanding and all held by LG&E and KU Energy LLC at ~~October 31, 2019.~~April 30, 2020.


Kentucky Utilities Company	Common stock, no par value, 37,817,878 shares outstanding and all held by LG&E and KU Energy LLC at ~~October 31, 2019.~~April 30, 2020.

This document is available free of charge at the Investors section of PPL Corporation's website at www.pplweb.com. However, other information on this website does not constitute a part of this Form 10-Q.

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PPL CORPORATION

PPL ELECTRIC UTILITIES CORPORATION

LG&E AND KU ENERGY LLC

LOUISVILLE GAS AND ELECTRIC COMPANY

KENTUCKY UTILITIES COMPANY

FORM 10-Q

FOR THE QUARTER ENDED ~~SEPTEMBER 30, 2019~~MARCH 31, 2020

Table of Contents

This combined Form 10-Q is separately filed by the following Registrants in their individual capacity: PPL Corporation, PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company and Kentucky Utilities Company. Information contained herein relating to any individual Registrant is filed by such Registrant solely on its own behalf, and no Registrant makes any representation as to information relating to any other Registrant, except that information under "Forward-Looking Information" relating to subsidiaries of PPL Corporation is also attributed to PPL Corporation and information relating to the subsidiaries of LG&E and KU Energy LLC is also attributed to LG&E and KU Energy LLC.

Unless otherwise specified, references in this Report, individually, to PPL Corporation, PPL Electric Utilities Corporation, LG&E and KU Energy LLC, Louisville Gas and Electric Company and Kentucky Utilities Company are references to such entities directly or to one or more of their subsidiaries, as the case may be, the financial results of which subsidiaries are consolidated into such Registrants' financial statements in accordance with GAAP. This presentation has been applied where identification of particular subsidiaries is not material to the matter being disclosed, and to conform narrative disclosures to the presentation of financial information on a consolidated basis.



				Page
GLOSSARY OF TERMS AND ABBREVIATIONS				i
FORWARD-LOOKING INFORMATION				1
PART I. FINANCIAL INFORMATION
	Item 1. Financial Statements
		PPL Corporation and Subsidiaries
			Condensed Consolidated Statements of Income	3
			Condensed Consolidated Statements of Comprehensive Income	4
			Condensed Consolidated Statements of Cash Flows	5
			Condensed Consolidated Balance Sheets	6
			Condensed Consolidated Statements of Equity	8
		PPL Electric Utilities Corporation and Subsidiaries
			Condensed Consolidated Statements of Income	10
			Condensed Consolidated Statements of Cash Flows	11
			Condensed Consolidated Balance Sheets	12
			Condensed Consolidated Statements of Equity	14
		LG&E and KU Energy LLC and Subsidiaries
			Condensed Consolidated Statements of Income	16
			Condensed Consolidated Statements of Cash Flows	17
			Condensed Consolidated Balance Sheets	18
			Condensed Consolidated Statements of Equity	20
		Louisville Gas and Electric Company
			Condensed Statements of Income	22
			Condensed Statements of Cash Flows	23
			Condensed Balance Sheets	24
			Condensed Statements of Equity	26
		Kentucky Utilities Company
			Condensed Statements of Income	28
			Condensed Statements of Cash Flows	29
			Condensed Balance Sheets	30
			Condensed Statements of Equity	32

Table of Contents



	Combined Notes to Condensed Financial Statements (Unaudited)
		Index to Combined Notes to Condensed Financial Statements		33
		1. Interim Financial Statements		33
		2. Summary of Significant Accounting Policies		3433
		3. Segment and Related Information		3536
		4. Revenue from Contracts with Customers		3637
		5. Earnings Per Share		39
		6. Income Taxes		40
		7. Utility Rate Regulation		4241
		8. Financing Activities		4644
		9. ~~Leases~~Defined Benefits		4947
		10. ~~Defined Benefits~~Commitments and Contingencies		5248
		11. ~~Commitments and Contingencies~~Related Party Transactions		5455
		12. ~~Related Party Transactions~~Other Income (Expense) - net		6357
		13. ~~Other Income (Expense) - net~~Fair Value Measurements		6557
		14. ~~Fair Value Measurements~~Derivative Instruments and Hedging Activities		6559
		15. ~~Derivative Instruments and Hedging Activities~~Asset Retirement Obligations		6866
		16. ~~Asset Retirement Obligations~~		75
		~~17.~~ Accumulated Other Comprehensive Income (Loss)		75
		~~18. New Accounting Guidance Pending Adoption~~		7667
	Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations
		Overview		7868
			Introduction	7868
			Business Strategy	8070
			Financial and Operational Developments	8171
		Results of Operations		8475
			PPL Corporation and Subsidiaries - Statement of Income Analysis, Segment Earnings and Adjusted Gross Margins	8576
			PPL Electric Utilities Corporation and Subsidiaries - Statement of Income Analysis ~~Earnings and Adjusted Gross Margins~~	9685
			LG&E and KU Energy LLC and Subsidiaries - Statement of Income Analysis ~~Earnings and Adjusted Gross Margins~~	9986
			Louisville Gas and Electric Company - Statement of Income Analysis ~~Earnings and Adjusted Gross Margins~~	~~103~~87
			Kentucky Utilities Company - Statement of Income Analysis ~~Earnings and Adjusted Gross Margins~~	~~106~~88
		Financial Condition		~~109~~89
			Liquidity and Capital Resources	~~109~~89
			Risk Management	~~115~~95
			Foreign Currency Translation	~~117~~97
			Related Party Transactions	~~117~~97
			Acquisitions, Development and Divestitures	~~117~~97
			Environmental Matters	~~118~~97
		New Accounting Guidance		~~118~~97
		Application of Critical Accounting Policies		~~119~~98
	Item 3. Quantitative and Qualitative Disclosures About Market Risk			~~120~~99
	Item 4. Controls and Procedures			~~120~~99
PART II. OTHER INFORMATION
	Item 1. Legal Proceedings			~~120~~99
	Item 1A. Risk Factors			~~120~~99
	Item 4. Mine Safety Disclosures			~~120~~100
	Item 5. Other Information			100
	Item 6. Exhibits			~~121~~100
SIGNATURES				~~122~~102
CERTIFICATES OF PRINCIPAL EXECUTIVE OFFICER AND PRINCIPAL FINANCIAL OFFICER PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002
CERTIFICATES OF PRINCIPAL EXECUTIVE OFFICER AND PRINCIPAL FINANCIAL OFFICER PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

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GLOSSARY OF TERMS AND ABBREVIATIONS

PPL Corporation and its subsidiaries

KU - Kentucky Utilities Company, a public utility subsidiary of LKE engaged in the regulated generation, transmission, distribution and sale of electricity, primarily in Kentucky.

LG&E - Louisville Gas and Electric Company, a public utility subsidiary of LKE engaged in the regulated generation, transmission, distribution and sale of electricity and the distribution and sale of natural gas in Kentucky.

LKE - LG&E and KU Energy LLC, a subsidiary of PPL and the parent of LG&E, KU and other subsidiaries.

LKS - LG&E and KU Services Company, a subsidiary of LKE that provides administrative, management, and support services primarily to LKE and its subsidiaries.

PPL - PPL Corporation, the parent holding company of PPL Electric, PPL Energy Funding, PPL Capital Funding, LKE and other subsidiaries.

PPL Capital Funding - PPL Capital Funding, Inc., a financing subsidiary of PPL that provides financing for the operations of PPL and certain subsidiaries. Debt issued by PPL Capital Funding is guaranteed as to payment by PPL.

PPL Electric - PPL Electric Utilities Corporation, a public utility subsidiary of PPL engaged in the regulated transmission and distribution of electricity in its Pennsylvania service area and that provides electricity supply to its retail customers in this area as a PLR.

PPL Energy Funding - PPL Energy Funding Corporation, a subsidiary of PPL and the parent holding company of PPL Global and other subsidiaries.

PPL EU Services - PPL EU Services Corporation, a subsidiary of PPL that provides administrative, management and support services primarily to PPL Electric.

PPL Global - PPL Global, LLC, a subsidiary of PPL Energy Funding that, primarily through its subsidiaries, owns and operates WPD, PPL's regulated electricity distribution businesses in the U.K.

PPL Services - PPL Services Corporation, a subsidiary of PPL that provides administrative, management and support services to PPL and its subsidiaries.

PPL WPD Limited - an indirect U.K. subsidiary of PPL Global. Following reorganizations in October 2015 and October 2017, PPL WPD Limited is an indirect parent to WPD plc having previously been a sister company.

Safari Energy - Safari Energy, LLC, an indirect subsidiary of PPL, acquired in June 2018, that provides solar energy solutions for commercial customers in the U.S.

WPD - refers to PPL WPD Limited and its subsidiaries.

WPD (East Midlands) - Western Power Distribution (East Midlands) plc, a British regional electricity distribution utility company.

WPD plc - Western Power Distribution plc, an indirect U.K. subsidiary of PPL WPD Limited. Its principal indirectly owned subsidiaries are WPD (East Midlands), WPD (South Wales), WPD (South West) and WPD (West Midlands).

WPD Midlands - refers to WPD (East Midlands) and WPD (West Midlands), collectively.

WPD (South Wales) - Western Power Distribution (South Wales) plc, a British regional electricity distribution utility company.

WPD (South West) - Western Power Distribution (South West) plc, a British regional electricity distribution utility company.

Table of Contents

WPD (West Midlands) - Western Power Distribution (West Midlands) plc, a British regional electricity distribution utility company.

WKE - Western Kentucky Energy Corp., a subsidiary of LKE that leased certain non-regulated utility generating plants in western Kentucky until July 2009.

Other terms and abbreviations

£ - British pound sterling.

~~2018~~2019 Form 10-K - Annual Report to the SEC on Form 10-K for the year ended December 31, ~~2018.~~2019.

Act 11 - Act 11 of 2012 that became effective on April 16, 2012. The Pennsylvania legislation authorized the PUC to approve two specific ratemaking mechanisms: the use of a fully projected future test year in base rate proceedings and, subject to certain conditions, a DSIC.

Act 129 - Act 129 of 2008 that became effective in October 2008. The law amended the Pennsylvania Public Utility Code and created an energy efficiency and conservation program and smart metering technology requirements, adopted new PLR electricity supply procurement rules, provided remedies for market misconduct and changed the Alternative Energy Portfolio Standard (AEPS).

Act 129 Smart Meter program - PPL Electric's system wide meter replacement program that installs wireless digital meters that provide secure communication between PPL Electric and the meter as well as all related infrastructure.

Adjusted Gross Margins - a non-GAAP financial measure of performance used in "Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" (MD&A).

AFUDC - allowance for funds used during construction. The cost of equity and debt funds used to finance construction projects of regulated businesses, which is capitalized as part of construction costs.

AOCI - accumulated other comprehensive income or loss.

ARO - asset retirement obligation.

ATM Program - at-the-market stock offering program.

CCR(s) - coal combustion residual(s). CCRs include fly ash, bottom ash and sulfur dioxide scrubber wastes.

Clean Air Act - federal legislation enacted to address certain environmental issues related to air emissions, including acid rain, ozone and toxic air emissions.

Clean Water Act - federal legislation enacted to address certain environmental issues relating to water quality including effluent discharges, cooling water intake, and dredge and fill activities.

COVID-19 - the disease caused by the novel coronavirus identified in 2019 that has caused a global pandemic in 2020.

CPCN - Certificate of Public Convenience and Necessity. Authority granted by the KPSC pursuant to Kentucky Revised Statute 278.020 to provide utility service to or for the public or the construction of certain plant, equipment, property or facility for furnishing of utility service to the public.

CPI -consumer price index, a measure of inflation in the U.K. published monthly by the Office for National Statistics.

CPIH - consumer price index including owner-occupiers' housing costs. An aggregate measure of changes in the cost of living in the U.K., including a measure of owner-occupiers' housing costs.

Customer Choice Act - the Pennsylvania Electricity Generation Customer Choice and Competition Act, legislation enacted to restructure the state's electric utility industry to create retail access to a competitive market for generation of electricity.

Table of Contents

DNO - Distribution Network Operator in the U.K.

DRIP - PPL Amended and Restated Dividend Reinvestment and Direct Stock Purchase Plan.

DSIC - Distribution System Improvement Charge. Authorized under Act 11, which is an alternative ratemaking mechanism providing more-timely cost recovery of qualifying distribution system capital expenditures.

~~Table of Contents~~

DSM - Demand Side Management. Pursuant to Kentucky Revised Statute 278.285, the KPSC may determine the reasonableness of DSM programs proposed by any utility under its jurisdiction. DSM programs consist of energy efficiency programs intended to reduce peak demand and delay the investment in additional power plant construction, provide customers with tools and information regarding their energy usage and support energy efficiency.

DSO - Distribution System Operation in the U.K. is the effective delivery of a range of functions and services that need to happen to run an advanced electricity distribution network. These functions cover long-term network planning; operations, real-time processes and planning, and markets and settlement. This does not focus on a single party as an operator; but recognizes roles for a range of parties to deliver DSO.

DSP - Default Service Provider.

Earnings from Ongoing Operations - a non-GAAP financial measure of earnings adjusted for the impact of special items and used in "Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" (MD&A).

ECR - Environmental Cost Recovery. Pursuant to Kentucky Revised Statute 278.183, Kentucky electric utilities are entitled to the current recovery of costs of complying with the Clean Air Act, as amended, and those federal, state or local environmental requirements that apply to coal combustion wastes and byproducts from the production of energy from coal.

ELG(s) - Effluent Limitation Guidelines, regulations promulgated by the EPA.

EPA - Environmental Protection Agency, a U.S. government agency.

EPS - earnings per share.

FERC - Federal Energy Regulatory Commission, the U.S. federal agency that regulates, among other things, interstate transmission and wholesale sales of electricity, hydroelectric power projects and related matters.

GAAP - Generally Accepted Accounting Principles in the U.S.

GBP - British pound sterling.

GHG(s) - greenhouse gas(es).

GLT - gas line tracker. The KPSC approved mechanism for LG&E's recovery of costs associated with gas transmission lines, gas service lines, gas risers, leak mitigation, and gas main replacements.

~~HB 487~~ ~~- House Bill 487. Comprehensive Kentucky state tax legislation enacted in April 2018.~~

IRS - Internal Revenue Service, a U.S. government agency.

KPSC - Kentucky Public Service Commission, the state agency that has jurisdiction over the regulation of rates and service of utilities in Kentucky.

LIBOR - London Interbank Offered Rate.

Moody's - Moody's Investors Service, Inc., a credit rating agency.

MW - megawatt, one thousand kilowatts.

~~NAAQS~~ ~~- National Ambient Air Quality Standards periodically adopted pursuant to the Clean Air Act.~~

NERC - North American Electric Reliability Corporation.

~~New Source Review~~ - a Clean Air Act program that requires industrial facilities to install updated pollution control equipment when they are built or when making a modification that increases emissions beyond certain allowable thresholds.

iii

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NPNS - the normal purchases and normal sales exception as permitted by derivative accounting rules. Derivatives that qualify for this exception may receive accrual accounting treatment.

OCI - other comprehensive income or loss.

Ofgem - Office of Gas and Electricity Markets, the British agency that regulates transmission, distribution and wholesale sales of electricity and gas and related matters.

~~iii~~

~~Table of Contents~~

OVEC - Ohio Valley Electric Corporation, located in Piketon, Ohio, an entity in which LKE indirectly owns an 8.13% interest (consists of LG&E's 5.63% and KU's 2.50% interests), which is recorded at cost. OVEC owns and operates two coal-fired power plants, the Kyger Creek plant in Ohio and the Clifty Creek plant in Indiana, with combined capacities of 2,120 MW.

~~Performance unit~~ - stock-based compensation award that represents a variable number of shares of PPL common stock that a recipient may receive based on PPL's attainment of (i) relative total shareowner return (TSR) over a three-year performance period as compared to companies in the Philadelphia Stock Exchange Utility Index; or (ii) corporate return on equity (ROE) based on the average of the annual ROE for each year of the three-year performance period.

PLR - Provider of Last Resort, the role of PPL Electric in providing default electricity supply within its delivery area to retail customers who have not chosen to select an alternative electricity supplier under the Customer Choice Act.

PP&E - property, plant and equipment.

PPL EnergyPlus - prior to the June 1, 2015 spinoff, PPL Energy Supply, LLC, PPL EnergyPlus, LLC, a subsidiary of PPL Energy Supply that marketed and traded wholesale and retail electricity and gas and supplied energy and energy services in competitive markets.

PPL Energy Supply - prior to the June 1, 2015 spinoff, PPL Energy Supply, LLC, a subsidiary of PPL Energy Funding and the indirect parent company of PPL Montana, LLC.

PPL Montana - prior to the June 1, 2015 spinoff of PPL Energy Supply, PPL Montana, LLC, an indirect subsidiary of PPL Energy Supply that generated electricity for wholesale sales in Montana and the Pacific Northwest.

PUC - Pennsylvania Public Utility Commission, the state agency that regulates certain ratemaking, services, accounting and operations of Pennsylvania utilities.

RAV - regulatory asset value. This term, used within the U.K. regulatory environment, is also commonly known as RAB or regulatory asset base. RAV is based on historical investment costs at time of privatization, plus subsequent allowed additions less annual regulatory depreciation, and represents the value on which DNOs earn a return in accordance with the regulatory cost of capital. RAV is indexed to Retail Price Index (RPI) in order to allow for the effects of inflation. RAV additions have been and continue to be based on a percentage of annual total expenditures that have a long-term benefit to WPD (similar to capital projects for the U.S. regulated businesses that are generally included in rate base).

RCRA - Resource Conservation and Recovery Act of 1976.

Registrant(s) - refers to the Registrants named on the cover of this Report (each a "Registrant" and collectively, the "Registrants").

Regulation S-X - SEC regulation governing the form and content of and requirements for financial statements required to be filed pursuant to the federal securities laws.

RFC - ReliabilityFirst Corporation, one of eight regional entities with delegated authority from NERC that work to safeguard the reliability of the bulk power systems throughout North America.

RIIO - Ofgem's framework for setting U.K. regulated gas and electric utility price controls which stands for "Revenues = Incentive + Innovation + Outputs." RIIO-1 refers to the first generation of price controls under the RIIO framework. RIIO-ED1 refers to the RIIO regulatory price control applicable to the operators of U.K. electricity distribution networks, the duration of which is April 2015 through March 2023. RIIO-2 refers to the second generation of price controls under the RIIO framework. RIIO-ED2 refers to the second generation of the RIIO regulatory price control applicable to the operators of U.K. electricity distribution networks, which will begin in April 2023.

Riverstone - Riverstone Holdings LLC, a Delaware limited liability company and, as of December 6, 2016, ultimate parent company of the entities that own the competitive power generation business contributed to Talen Energy.

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RPI - retail price index, is a measure of inflation in the United Kingdom published monthly by the Office for National Statistics.

~~Table of Contents~~

Sarbanes-Oxley - Sarbanes-Oxley Act of 2002, which sets requirements for management's assessment of internal controls for financial reporting. It also requires an independent auditor to make its own assessment.

~~SCRs~~ ~~- selective catalytic reduction, a pollution control process for the removal of nitrogen oxide from exhaust gas.~~

Scrubber - an air pollution control device that can remove particulates and/or gases (primarily sulfur dioxide) from exhaust gases.

SEC - the U.S. Securities and Exchange Commission, a U.S. government agency primarily responsible to protect investors and maintain the integrity of the securities markets.

SERC - SERC Reliability Corporation, one of eight regional entities with delegated authority from NERC that work to safeguard the reliability of the bulk power systems throughout North America.

Smart metering technology - technology that can measure, among other things, time of electricity consumption to permit offering rate incentives for usage during lower cost or demand intervals. The use of this technology also has the potential to strengthen network reliability.

S&P - S&P Global Ratings, a credit rating agency.

Superfund - federal environmental statute that addresses remediation of contaminated sites; states also have similar statutes.

Talen Energy - Talen Energy Corporation, the Delaware corporation formed to be the publicly traded company and owner of the competitive generation assets of PPL Energy Supply and certain affiliates of Riverstone, which as of December 6, 2016, became wholly owned by Riverstone.

Talen Energy Marketing - Talen Energy Marketing, LLC, the new name of PPL EnergyPlus subsequent to the spinoff of PPL Energy Supply.

TCJA - Tax Cuts and Jobs Act. Comprehensive U.S. federal tax legislation enacted on December 22, 2017.

Treasury Stock Method - a method applied to calculate diluted EPS that assumes any proceeds that could be obtained upon exercise of options and warrants (and their equivalents) would be used to purchase common stock at the average market price during the relevant period.

VEBA - Voluntary Employee Beneficiary Association. A tax-exempt trust under the Internal Revenue Code Section 501(c)(9) used by employers to fund and pay eligible medical, life and similar benefits.

VSCC - Virginia State Corporation Commission, the state agency that has jurisdiction over the regulation of Virginia corporations, including utilities.

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Forward-looking Information

Statements contained in this Form 10-Q concerning expectations, beliefs, plans, objectives, goals, strategies, future events or performance and underlying assumptions and other statements that are other than statements of historical fact are "forward-looking statements" within the meaning of the federal securities laws. Although the Registrants believe that the expectations and assumptions reflected in these statements are reasonable, there can be no assurance that these expectations will prove to be correct. Forward-looking statements are subject to many risks and uncertainties, and actual results may differ materially from the results discussed in forward-looking statements. In addition to the specific factors discussed in each Registrant's ~~2018~~2019 Form 10-K and in "Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" in this Form 10-Q, the following are among the important factors that could cause actual results to differ materially and adversely from the forward-looking statements:

the COVID-19 pandemic and its impact on economic conditions and financial markets;

other pandemic health events or other catastrophic events such as fires, earthquakes, explosions, floods, droughts, tornadoes, hurricanes and other storms;

the outcome of rate cases or other cost recovery or revenue proceedings;

changes in U.S. state or federal or U.K. tax laws or regulations;

the direct or indirect effects on PPL or its subsidiaries or business systems of cyber-based intrusion or the threat of cyberattacks;

significant decreases in demand for electricity in the U.S.;

expansion of alternative and distributed sources of electricity generation and storage;

changes in foreign currency exchange rates for British pound sterling and the related impact on unrealized gains and losses on PPL's foreign currency economic hedges;

the effectiveness of our risk management programs, including foreign currency and interest rate hedging;

non-achievement by WPD of performance targets set by Ofgem;

the effect of changes in RPI on WPD's revenues and index linked debt;

developments related to the U.K.'s ~~plans to withdraw~~withdrawal from the European Union and any ~~actions in response~~responses thereto;

the amount of WPD's pension deficit funding recovered in revenues after March 31, 2021, following the triennial pension review ~~that~~which began in March ~~2019;~~2019 and is due to conclude at the end of 2020;

defaults by counterparties or suppliers for energy, capacity, coal, natural gas or key commodities, goods or services;

capital market conditions, including the availability of capital or credit, changes in interest rates and certain economic indices, and decisions regarding capital structure;

a material decline in the market value of PPL's equity;

significant decreases in the fair value of debt and equity securities and its impact on the value of assets in defined benefit plans, and the potential cash funding requirements if fair value declines;

interest rates and their effect on pension and retiree medical liabilities, ARO liabilities and interest payable on certain debt securities;

volatility in or the impact of other changes in financial markets and economic conditions;

the potential impact of any unrecorded commitments and liabilities of the Registrants and their subsidiaries;

new accounting requirements or new interpretations or applications of existing requirements;

changes in the corporate credit ratings or securities analyst rankings of the Registrants and their securities;

any requirement to record impairment charges pursuant to GAAP with respect to any of our significant investments;

laws or regulations to reduce emissions of GHGs or the physical effects of climate change;

continuing ability to access fuel supply for LG&E and KU, as well as the ability to recover fuel costs and environmental expenditures in a timely manner at LG&E and KU and natural gas supply costs at LG&E;

weather and other conditions affecting generation, transmission and distribution operations, operating costs and customer energy use;

~~catastrophic events such as fires, earthquakes, explosions, floods, tornadoes, hurricanes and other storms, droughts, pandemic health events or other similar occurrences;~~

war, armed conflicts, terrorist attacks, or similar disruptive events;

changes in political, regulatory or economic conditions in states, regions or countries where the Registrants or their subsidiaries conduct business;

receipt of necessary governmental permits and approvals;

new state, federal or foreign legislation or regulatory developments;

the impact of any state, federal or foreign investigations applicable to the Registrants and their subsidiaries and the energy industry;

our ability to attract and retain qualified employees;

the effect of any business or industry restructuring;

development of new projects, markets and technologies;

performance of new ventures;

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business dispositions or acquisitions and our ability to realize expected benefits from such business transactions;

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collective labor bargaining negotiations; and

the outcome of litigation against the Registrants and their subsidiaries.

Any forward-looking statements should be considered in light of ~~such~~these important factors and in conjunction with other documents of the Registrants on file with the SEC.

New factors that could cause actual results to differ materially from those described in forward-looking statements emerge from time to time, and it is not possible for the Registrants to predict all such factors, or the extent to which any such factor or combination of factors may cause actual results to differ from those ~~expressed~~contained in any forward-looking statement. Any forward-looking statement speaks only as of the date on which such statement is made, and the Registrants undertake no obligation to update the information contained in ~~such~~the statement to reflect subsequent developments or information.

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PART I. FINANCIAL INFORMATION

ITEM 1. Financial Statements

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, except share data)


	Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended March 31,
	2019		2018		2019		2018		2020		2019
Operating Revenues	$	1,933	$	1,872	$	5,815	$	5,846	$	2,054	$	2,079

Operating Expenses
Operation
Fuel	194		206		556		609		163		194
Energy purchases	150		149		538		538		201		250
Other operation and maintenance	480		479		1,452		1,453		476		490
Depreciation	306		275		890		817		317		284
Taxes, other than income	77		77		232		234		80		80
Total Operating Expenses	1,207		1,186		3,668		3,651		1,237		1,298

Operating Income	726		686		2,147		2,195		817		781

Other Income (Expense) - net	126		106		309		297		125		52

Interest Expense	259		244		746		718		248		241

Income Before Income Taxes	593		548		1,710		1,774		694		592

Income Taxes	118		103		328		362		140		126

Net Income	$	475	$	445	$	1,382	$	1,412	$	554	$	466

Earnings Per Share of Common Stock:
Net Income Available to PPL Common Shareowners:
Basic	$	0.66	$	0.63	$	1.91	$	2.02	$	0.72	$	0.65
Diluted	$	0.65	$	0.62	$	1.89	$	2.01	$	0.72	$	0.64

Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic	722,259		703,730		721,693		699,117		767,948		721,023
Diluted	731,151		710,517		730,677		702,305		768,738		729,953

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Three Months Ended September 30,						Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2019			2018			2020			2019
Net income	$	475		$	445		$	1,382		$	1,412		$	554		$	466

Other comprehensive income (loss):
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Foreign currency translation adjustments, net of tax of $0, $0, $0, ($2)	(285		)	(187		)	(368		)	(321		)
Qualifying derivatives, net of tax of ($3), ($5), ($7), ($5)	16			22			32			21
Foreign currency translation adjustments, net of tax of $0, $0													(61		)	294
Qualifying derivatives, net of tax of ($2), $4													8			(19		)
Defined benefit plans:
Prior service costs, net of tax of $0, $0, $0, $0	—			—			—			(1		)
Net actuarial gain (loss), net of tax of $2, $3, $4, $3	(5		)	(8		)	(10		)	(9		)
Net actuarial gain (loss), net of tax of $0, $1													—			(3		)
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax of $3, $3, $3, $4	(22		)	(14		)	(25		)	(21		)
Qualifying derivatives, net of tax of $0, ($6)													(3		)	24
Defined benefit plans:
Prior service costs, net of tax of ($1), ($1), ($1), ($1)	—			—			1			1
Net actuarial (gain) loss, net of tax of ($5), ($8), ($16), ($26)	20			34			62			104
Prior service costs, net of tax of $0, $0													1			—
Net actuarial (gain) loss, net of tax of ($12), ($5)													47			21
Total other comprehensive income (loss)	(276		)	(153		)	(308		)	(226		)	(8		)	317

Comprehensive income	$	199		$	292		$	1,074		$	1,186		$	546		$	783

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2020			2019
Cash Flows from Operating Activities
Net income	$	1,382		$	1,412		$	554		$	466
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	890			817			317			284
Amortization	60			56			12			22
Defined benefit plans - income	(198		)	(146		)
Defined benefit plans - (income) expense							(52		)	(66		)
Deferred income taxes and investment tax credits	257			255			106			89
Unrealized gains on derivatives, and other hedging activities	(18		)	(129		)
Unrealized (gains) losses on derivatives, and other hedging activities							(57		)	53
Stock-based compensation expense	24			21			6			14
Other	(15		)	(12		)	17			(3		)
Change in current assets and current liabilities
Accounts receivable	57			38			(35		)	(57		)
Accounts payable	(116		)	(55		)	(63		)	(94		)
Unbilled revenues	58			129			68			48
Fuel, materials and supplies	9			25			13			31
Prepayments	(53		)	(38		)	(76		)	(86		)
Regulatory assets and liabilities, net	(62		)	39			(25		)	(25		)
Accrued interest	74			48			59			48
Other current liabilities	(94		)	(36		)	(95		)	(72		)
Other	(6		)	(1		)	24			(21		)
Other operating activities
Defined benefit plans - funding	(281		)	(284		)	(125		)	(127		)
Proceeds from transfer of excess benefit plan funds	—			65
Other assets	(24		)	(38		)	42			(20		)
Other liabilities	(56		)	44			2			(10		)
Net cash provided by operating activities	1,888			2,210			692			474
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(2,197		)	(2,344		)	(826		)	(729		)
Purchase of investments	(55		)	(65		)	—			(55		)
Proceeds from the sale of investments	63			3			—			57
Other investing activities	(5		)	(60		)	(7		)	5
Net cash used in investing activities	(2,194		)	(2,466		)	(833		)	(722		)
Cash Flows from Financing Activities
Issuance of long-term debt	1,465			602
Retirement of long-term debt	(200		)	(277		)
Issuance of common stock	49			678			20			22
Payment of common stock dividends	(893		)	(846		)	(317		)	(296		)
Issuance of term loan							200			—
Net increase (decrease) in short-term debt	(34		)	481			345			424
Other financing activities	(24		)	(20		)	(8		)	(8		)
Net cash provided by financing activities	363			618			240			142
Effect of Exchange Rates on Cash, Cash Equivalents and Restricted Cash	(10		)	(9		)	1			3
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	47			353			100			(103		)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	643			511			836			643
Cash, Cash Equivalents and Restricted Cash at End of Period	$	690		$	864		$	936		$	540

Supplemental Disclosures of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at September 30,	$	363		$	311
Accrued expenditures for intangible assets at September 30,	$	67		$	70
Accrued expenditures for property, plant and equipment at March 31,							$	282		$	322
Accrued expenditures for intangible assets at March 31,							$	87		$	64

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
Assets

Current Assets
Cash and cash equivalents	$	670	$	621	$	915	$	815
Accounts receivable (less reserve: 2019, $60; 2018, $56)
Accounts receivable (less reserve: 2020, $62; 2019, $58)
Customer	625		663		730		687
Other	112		107		107		105
Unbilled revenues	430		496
Unbilled revenues (less reserve: 2020, $3; 2019, $0)					434		504
Fuel, materials and supplies	295		303		320		332
Prepayments	115		70		155		79
Price risk management assets	209		109		193		147
Other current assets	78		63		102		98
Total Current Assets	2,534		2,432		2,956		2,767

Property, Plant and Equipment
Regulated utility plant	40,734		39,734		43,109		42,709
Less: accumulated depreciation - regulated utility plant	7,732		7,310		8,212		8,055
Regulated utility plant, net	33,002		32,424		34,897		34,654
Non-regulated property, plant and equipment	331		355		380		357
Less: accumulated depreciation - non-regulated property, plant and equipment	105		101		87		109
Non-regulated property, plant and equipment, net	226		254		293		248
Construction work in progress	1,880		1,780		1,645		1,580
Property, Plant and Equipment, net	35,108		34,458		36,835		36,482

Other Noncurrent Assets
Regulatory assets	1,658		1,673		1,477		1,492
Goodwill	3,050		3,162		3,178		3,198
Other intangibles	709		716		748		742
Pension benefit asset	955		535		603		464
Price risk management assets	210		228		166		149
Other noncurrent assets	335		192		365		386
Total Other Noncurrent Assets	6,917		6,506		6,537		6,431

Total Assets	$	44,559	$	43,396	$	46,328	$	45,680

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2019			December 31, 2018			March 31, 2020			December 31, 2019
Liabilities and Equity

Current Liabilities
Short-term debt	$	1,387		$	1,430		$	1,696		$	1,151
Long-term debt due within one year	—			530			1,170			1,172
Accounts payable	846			989			833			956
Taxes	94			110			100			99
Interest	346			278			352			294
Dividends	298			296			319			317
Customer deposits	262			257			265			261
Regulatory liabilities	79			122			99			115
Other current liabilities	528			551			488			535
Total Current Liabilities	3,840			4,563			5,322			4,900

Long-term Debt	21,547			20,069			20,670			20,721

Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	3,076			2,796			3,217			3,088
Investment tax credits	124			126			123			124
Accrued pension obligations	719			771			500			587
Asset retirement obligations	193			264			217			212
Regulatory liabilities	2,675			2,714			2,557			2,572
Other deferred credits and noncurrent liabilities	483			436			481			485
Total Deferred Credits and Other Noncurrent Liabilities	7,270			7,107			7,095			7,068

Commitments and Contingent Liabilities (Notes 7 and 11)
Commitments and Contingent Liabilities (Notes 7 and 10)

Equity
Common stock - $0.01 par value (a)	7			7			8			8
Additional paid-in capital	11,087			11,021			12,239			12,214
Earnings reinvested	5,080			4,593			5,360			5,127
Accumulated other comprehensive loss	(4,272		)	(3,964		)	(4,366		)	(4,358		)
Total Equity	11,902			11,657			13,241			12,991

Total Liabilities and Equity	$	44,559		$	43,396		$	46,328		$	45,680


(a)	1,560,000 shares authorized; ~~722,307~~768,266 and ~~720,323~~767,233 shares issued and outstanding at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018.~~2019.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Common stock shares outstanding (a)	Common stock		Additional paid-in capital			Earnings reinvested			Accumulated other comprehensive loss			Total			Common stock shares outstanding (a)	Common stock		Additional paid-in capital			Earnings reinvested			Accumulated other comprehensive loss			Total
June 30, 2019	721,840	$	7	$	11,069		$	4,903		$	(3,996	)	$	11,983
December 31, 2019																767,233	$	8	$	12,214		$	5,127		$	(4,358	)	$	12,991
Common stock issued	467			14									14			1,033			34									34
Stock-based compensation				4									4						(9		)							(9		)
Net income							475						475									554						554
Dividends and dividend equivalents (b)							(298		)				(298		)							(319		)				(319		)
Other comprehensive income (loss)										(276		)	(276		)										(8		)	(8		)
September 30, 2019	722,307	$	7	$	11,087		$	5,080		$	(4,272	)	$	11,902
Adoption of financial instrument credit losses guidance cumulative effect adjustment (Note 2), net of tax of $0																						(2		)				(2		)
March 31, 2020																768,266	$	8	$	12,239		$	5,360		$	(4,366	)	$	13,241

December 31, 2018	720,323	$	7	$	11,021		$	4,593		$	(3,964	)	$	11,657		720,323	$	7	$	11,021		$	4,593		$	(3,964	)	$	11,657
Common stock issued	1,984			61									61			1,048			32									32
Stock-based compensation				5									5						(2		)							(2		)
Net income							1,382						1,382									466						466
Dividends and dividend equivalents (b)							(895		)				(895		)							(298		)				(298		)
Other comprehensive income (loss)										(308		)	(308		)										317			317
September 30, 2019	722,307	$	7	$	11,087		$	5,080		$	(4,272	)	$	11,902
March 31, 2019																721,371	$	7	$	11,051		$	4,761		$	(3,647	)	$	12,172

June 30, 2018	699,128	$	7	$	10,462		$	4,266		$	(3,495	)	$	11,240
Common stock issued	20,574			536									536
Stock-based compensation				3									3
Net income							445						445
Dividends and dividend equivalents (b)							(288		)				(288		)
Other comprehensive income (loss)										(153		)	(153		)
September 30, 2018	719,702	$	7	$	11,001		$	4,423		$	(3,648	)	$	11,783

December 31, 2017	693,398	$	7	$	10,305		$	3,871		$	(3,422	)	$	10,761
Common stock issued	26,304			699									699
Stock-based compensation				(3		)							(3		)
Net income							1,412						1,412
Dividends and dividend equivalents (b)							(860		)				(860		)
Other comprehensive income (loss)										(226		)	(226		)
September 30, 2018	719,702	$	7	$	11,001		$	4,423		$	(3,648	)	$	11,783


(a)	Shares in thousands. Each share entitles the holder to 1 vote on any question presented at any shareowners' meeting.


(b)	Dividends declared per share of common stock were $0.4150 and $0.4125 ~~and $1.2375 for the three and nine months ended~~at ~~September 30, 2019~~March 31, 2020 and ~~$0.4100 and $1.23 for the three and nine months ended~~ ~~September 30, 2018~~March 31, 2019.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED STATEMENTS OF INCOME

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended March 31,
	2019		2018		2019		2018		2020		2019
Operating Revenues	$	590	$	548	$	1,756	$	1,704	$	608	$	645

Operating Expenses
Operation
Energy purchases	132		127		413		403		144		171
Other operation and maintenance	137		127		417		419		137		150
Depreciation	99		89		290		262		98		95
Taxes, other than income	29		27		84		81		30		31
Total Operating Expenses	397		370		1,204		1,165		409		447

Operating Income	193		178		552		539		199		198

Other Income (Expense) - net	7		5		18		18		3		5

Interest Income from Affiliate	1		4		3		5		1		2

Interest Expense	43		41		126		117		44		42

Income Before Income Taxes	158		146		447		445		159		163

Income Taxes	40		35		114		111		41		42

Net Income (a)	$	118	$	111	$	333	$	334	$	118	$	121


(a)	Net income equals comprehensive income.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2020			2019
Cash Flows from Operating Activities
Net income	$	333		$	334		$	118		$	121
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	290			262			98			95
Amortization	18			17			5			5
Defined benefit plans - expense	—			2
Deferred income taxes and investment tax credits	70			77			32			16
Other	(14		)	(13		)	8			(2		)
Change in current assets and current liabilities
Accounts receivable	34			22			(26		)	(25		)
Accounts payable	(46		)	(46		)	(20		)	(5		)
Unbilled revenues	28			45			34			13
Prepayments	(36		)	(25		)	(76		)	(88		)
Regulatory assets and liabilities, net	(42		)	(25		)	(11		)	(15		)
Taxes payable	(4		)	(1		)	(2		)	(2		)
Other	(20		)	12			(19		)	(12		)
Other operating activities
Defined benefit plans - funding	(21		)	(28		)	(21		)	(21		)
Other assets	11			(37		)	4			2
Other liabilities	8			54			8			(1		)
Net cash provided by operating activities	609			650			132			81

Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(815		)	(835		)	(280		)	(264		)
Expenditures for intangible assets	(4		)	—			(1		)	—
Net increase in notes receivable from affiliate	(546		)	—
Other investing activities	4			(2		)
Net cash used in investing activities	(1,361		)	(837		)	(281		)	(264		)

Cash Flows from Financing Activities
Issuance of long-term debt	393			398
Contributions from parent	400			429
Payment of common stock dividends to parent	(276		)	(271		)	(165		)	(120		)
Net increase in short-term debt							85			60
Other financing activities	(5		)	(4		)	—			(1		)
Net cash provided by financing activities	512			552
Net cash used in financing activities							(80		)	(61		)

Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	(240		)	365			(229		)	(244		)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	269			51			264			269
Cash, Cash Equivalents and Restricted Cash at End of Period	$	29		$	416		$	35		$	25

Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at September 30,	$	168		$	171
Accrued expenditures for property, plant and equipment at March 31,							$	158		$	142

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
Assets

Current Assets
Cash and cash equivalents	$	27	$	267	$	33	$	262
Accounts receivable (less reserve: 2019, $27; 2018, $27)
Accounts receivable (less reserve: 2020, $31; 2019, $28)
Customer	253		264		289		258
Other	26		38		18		22
Accounts receivable from affiliates	11		11		10		11
Notes receivable from affiliate	546		—
Unbilled revenues	92		120
Unbilled revenues (less reserve: 2020, $2; 2019, $0)					100		134
Materials and supplies	32		25		48		33
Prepayments	34		5		82		6
Regulatory assets	22		11		23		26
Other current assets	10		9		10		9
Total Current Assets	1,053		750		613		761

Property, Plant and Equipment
Regulated utility plant	12,261		11,637		12,750		12,589
Less: accumulated depreciation - regulated utility plant	3,031		2,856		3,137		3,078
Regulated utility plant, net	9,230		8,781		9,613		9,511
Construction work in progress	669		586		633		597
Property, Plant and Equipment, net	9,899		9,367		10,246		10,108

Other Noncurrent Assets
Regulatory assets	807		824		710		726
Intangibles	262		260		264		263
Other noncurrent assets	50		42		49		43
Total Other Noncurrent Assets	1,119		1,126		1,023		1,032

Total Assets	$	12,071	$	11,243	$	11,882	$	11,901

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
Liabilities and Equity

Current Liabilities
Short-term debt					$	85	$	—
Accounts payable	$	379	$	418	394		438
Accounts payable to affiliates	28		25		34		32
Taxes	8		12		11		13
Interest	43		37		48		41
Regulatory liabilities	48		74		83		96
Other current liabilities	86		101		75		93
Total Current Liabilities	592		667		730		713

Long-term Debt	4,085		3,694		3,986		3,985

Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	1,414		1,320		1,487		1,447
Accrued pension obligations	254		282		153		179
Regulatory liabilities	654		675		595		599
Other deferred credits and noncurrent liabilities	154		144		146		146
Total Deferred Credits and Other Noncurrent Liabilities	2,476		2,421		2,381		2,371

Commitments and Contingent Liabilities (Notes 7 and 11)
Commitments and Contingent Liabilities (Note 10)

Equity
Common stock - no par value (a)	364		364		364		364
Additional paid-in capital	3,558		3,158		3,558		3,558
Earnings reinvested	996		939		863		910
Total Equity	4,918		4,461		4,785		4,832

Total Liabilities and Equity	$	12,071	$	11,243	$	11,882	$	11,901


(a)	170,000 shares authorized; 66,368 shares issued and outstanding at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018.~~2019.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

Table of Contents

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

Common
stock
shares
outstanding
(a)

Common
stock

Additional
paid-in
capital

Earnings
reinvested
Total
June 30, 2019 66,368
$ 364
$ 3,158
$ 939
$ 4,461
Net income 118
118
Capital contributions from parent 400
400
Dividends declared on common stock (61 ) (61 )
September 30, 2019 66,368
$ 364
$ 3,558
$ 996
$ 4,918

December 31, 2018 66,368
$ 364
$ 3,158
$ 939
$ 4,461
Net income

333
333
Capital contributions from parent

400

400
Dividends declared on common stock

(276 ) (276 )
September 30, 2019 66,368
$ 364
$ 3,558
$ 996
$ 4,918

June 30, 2018 66,368
$ 364
$ 3,154
$ 900
$ 4,418
Net income 111
111
Capital contributions from parent 4
4
Dividends declared on common stock (49 ) (49 )
September 30, 2018 66,368
$ 364
$ 3,158
$ 962
$ 4,484

December 31, 2017 66,368
$ 364
$ 2,729
$ 899
$ 3,992
Net income

334
334
Capital contributions from parent

429

429
Dividends declared on common stock

(271 ) (271 )
September 30, 2018 66,368
$ 364
$ 3,158
$ 962
$ 4,484



	Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Earnings reinvested			Total
December 31, 2019	66,368	$	364	$	3,558	$	910		$	4,832
Net income						118			118
Dividends declared on common stock						(165		)	(165		)
March 31, 2020	66,368	$	364	$	3,558	$	863		$	4,785

December 31, 2018	66,368	$	364	$	3,158	$	939		$	4,461
Net income						121			121
Dividends declared on common stock						(120		)	(120		)
March 31, 2019	66,368	$	364	$	3,158	$	940		$	4,462


(a)	Shares in thousands. All common shares of PPL Electric stock are owned by PPL.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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Table of Contents

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Three Months Ended September 30,				Nine Months Ended September 30,					Three Months Ended March 31,
	2019		2018		2019		2018			2020		2019
Operating Revenues	$	844	$	802	$	2,421	$	2,417		$	825	$	845

Operating Expenses
Operation
Fuel	194		206		556		609			163		194
Energy purchases	19		22		125		135			57		79
Other operation and maintenance	205		216		627		632			204		214
Depreciation	144		119		402		354			149		123
Taxes, other than income	19		18		55		53			18		18
Total Operating Expenses	581		581		1,765		1,783			591		628

Operating Income	263		221		656		634			234		217

Other Income (Expense) - net	2		—		2		(2		)

Interest Expense	57		52		169		154			58		54

Interest Expense with Affiliate	7		7		23		18			7		7

Income Before Income Taxes	201		162		466		460			169		156

Income Taxes	43		32		78		102			34		32

Net Income (a)	$	158	$	130	$	388	$	358		$	135	$	124


(a)	Net income approximates comprehensive income.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

Table of Contents

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2020			2019
Cash Flows from Operating Activities
Net income	$	388		$	358		$	135		$	124
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	402			354			149			123
Amortization	20			13			4			10
Defined benefit plans - expense	9			12			5			3
Deferred income taxes and investment tax credits	78			71			31			36
Other	(2		)	(2		)	—			(1		)
Change in current assets and current liabilities
Accounts receivable	13			8			20			8
Accounts payable	(34		)	4			(18		)	(33		)
Accounts payable to affiliates	6			7			1			7
Unbilled revenues	5			54			27			21
Fuel, materials and supplies	16			17			24			29
Regulatory assets and liabilities, net	(19		)	62			(14		)	(10		)
Taxes payable	(7		)	(11		)	(27		)	(29		)
Accrued interest	57			41			51			42
Other	(31		)	(36		)	(37		)	(15		)
Other operating activities
Defined benefit plans - funding	(34		)	(126		)	(23		)	(21		)
Expenditures for asset retirement obligations	(67		)	(46		)	(15		)	(21		)
Other assets	(4		)	(1		)	1			(2		)
Other liabilities	17			8			6			(1		)
Net cash provided by operating activities	813			787			320			270
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(761		)	(826		)	(255		)	(278		)
Other investing activities	—			1
Net cash used in investing activities	(761		)	(825		)	(255		)	(278		)
Cash Flows from Financing Activities
Net increase (decrease) in notes payable with affiliate	16			(145		)	92			74
Issuance of long-term debt with affiliate	—			250
Issuance of long-term debt	705			118
Retirement of long-term debt	(200		)	(27		)
Acquisition of outstanding bonds	(40		)	—
Remarketing of reacquired bonds	40			—
Net increase (decrease) in short-term debt	(413		)	60
Net decrease in short-term debt							(85		)	(12		)
Distributions to member	(206		)	(217		)	(52		)	(56		)
Contributions from member	63			—
Other financing activities	(11		)	(2		)
Net cash provided by (used in) financing activities	(46		)	37			(45		)	6
Net Increase (Decrease) in Cash and Cash Equivalents	6			(1		)	20			(2		)
Cash and Cash Equivalents at Beginning of Period	24			30			27			24
Cash and Cash Equivalents at End of Period	$	30		$	29		$	47		$	22

Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at September 30,	$	107		$	108
Accrued expenditures for property, plant and equipment at March 31,							$	78		$	88

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

Table of Contents

CONDENSED CONSOLIDATED BALANCE SHEETS

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)


	September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
Assets

Current Assets
Cash and cash equivalents	$	30	$	24	$	47	$	27
Accounts receivable (less reserve: 2019, $28; 2018, $27)
Accounts receivable (less reserve: 2020, $27; 2019, $28)
Customer	233		239		246		260
Other	72		63		65		71
Unbilled revenues	164		169
Unbilled revenues (less reserve: 2020, $0; 2019, $0)					137		164
Fuel, materials and supplies	233		248		226		250
Prepayments	31		25		23		30
Regulatory assets	27		25		52		41
Other current assets					—		2
Total Current Assets	790		793		796		845

Property, Plant and Equipment
Regulated utility plant	14,175		13,721		14,798		14,646
Less: accumulated depreciation - regulated utility plant	2,294		2,125		2,401		2,356
Regulated utility plant, net	11,881		11,596		12,397		12,290
Construction work in progress	1,033		1,018		793		794
Property, Plant and Equipment, net	12,914		12,614		13,190		13,084

Other Noncurrent Assets
Regulatory assets	851		849		767		766
Goodwill	996		996		996		996
Other intangibles	72		78		67		69
Other noncurrent assets	145		82		126		171
Total Other Noncurrent Assets	2,064		2,005		1,956		2,002

Total Assets	$	15,768	$	15,412	$	15,942	$	15,931

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

Table of Contents

CONDENSED CONSOLIDATED BALANCE SHEETS

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)


	September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
Liabilities and Equity

Current Liabilities
Short-term debt	$	101	$	514	$	303	$	388
Long-term debt due within one year	—		530		975		975
Notes payable with affiliates	129		113		242		150
Accounts payable	304		366		257		316
Accounts payable to affiliates	15		9		12		11
Customer deposits	62		61		64		62
Taxes	56		63		31		58
Price risk management liabilities	5		4		4		4
Regulatory liabilities	31		48		16		19
Interest	89		32		91		40
Asset retirement obligations	92		82		66		70
Other current liabilities	131		126		116		153
Total Current Liabilities	1,015		1,948		2,177		2,246

Long-term Debt
Long-term debt	5,351		4,322		4,378		4,377
Long-term debt to affiliate	650		650		650		650
Total Long-term Debt	6,001		4,972		5,028		5,027

Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	1,060		956		1,111		1,069
Investment tax credits	124		126		123		124
Price risk management liabilities	20		16		25		17
Accrued pension obligations	262		282		184		233
Asset retirement obligations	147		214		151		145
Regulatory liabilities	2,021		2,039		1,962		1,973
Other deferred credits and noncurrent liabilities	152		136		155		155
Total Deferred Credits and Other Noncurrent Liabilities	3,786		3,769		3,711		3,716

Commitments and Contingent Liabilities (Notes 7 and 11)
Commitments and Contingent Liabilities (Notes 7 and 10)

Member's Equity	4,966		4,723		5,026		4,942

Total Liabilities and Equity	$	15,768	$	15,412	$	15,942	$	15,931

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

Table of Contents

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

LG&E and KU Energy LLC and Subsidiaries

(Unaudited)

(Millions of Dollars)


	Member's Equity			Member's Equity
June 30, 2019	$	4,877
December 31, 2019				$	4,942
Net income	158			135
Distributions to member	(69		)	(52		)
September 30, 2019	$	4,966
Other comprehensive income (loss)				1
March 31, 2020				$	5,026

December 31, 2018	$	4,723		$	4,723
Net income	388			124
Contributions from member	63
Distributions to member	(206		)	(56		)
Other comprehensive income (loss)	(2		)
September 30, 2019	$	4,966

June 30, 2018	$	4,632
Net income	130
Distributions to member	(56		)
Other comprehensive income	2
September 30, 2018	$	4,708

December 31, 2017	$	4,563
Net income	358
Distributions to member	(217		)
Other comprehensive income	4
September 30, 2018	$	4,708
March 31, 2019				$	4,791

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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Table of Contents

CONDENSED STATEMENTS OF INCOME

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars)


	Three Months Ended September 30,					Nine Months Ended September 30,						Three Months Ended March 31,
	2019		2018			2019			2018			2020			2019
Operating Revenues
Retail and wholesale	$	380	$	357		$	1,105		$	1,095		$	393		$	397
Electric revenue from affiliate	2		5			21			21			14			13
Total Operating Revenues	382		362			1,126			1,116			407			410

Operating Expenses
Operation
Fuel	79		83			226			234			74			78
Energy purchases	14		17			110			121			52			74
Energy purchases from affiliate	2		2			6			10			—			2
Other operation and maintenance	92		95			282			277			92			94
Depreciation	61		49			168			146			64			51
Taxes, other than income	10		9			29			27			10			9
Total Operating Expenses	258		255			821			815			292			308

Operating Income	124		107			305			301			115			102

Other Income (Expense) - net	—		(3		)	(1		)	(5		)	(1		)	—

Interest Expense	22		20			65			57			22			21

Income Before Income Taxes	102		84			239			239			92			81

Income Taxes	22		18			51			51			19			17

Net Income (a)	$	80	$	66		$	188		$	188		$	73		$	64


(a)	Net income equals comprehensive income.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

Table of Contents

CONDENSED STATEMENTS OF CASH FLOWS

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars)


	Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2020			2019
Cash Flows from Operating Activities
Net income	$	188		$	188		$	73		$	64
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	168			146			64			51
Amortization	13			10			2			7
Defined benefit plans - expense							1			—
Deferred income taxes and investment tax credits	45			46			1			13
Other	2			2
Change in current assets and current liabilities
Accounts receivable	13			14			14			3
Accounts receivable from affiliates	9			2			(6		)	(4		)
Accounts payable	(10		)	14			(12		)	(7		)
Accounts payable to affiliates	(5		)	(2		)	(4		)	(3		)
Unbilled revenues	4			30			11			13
Fuel, materials and supplies	7			9			27			32
Regulatory assets and liabilities, net	(5		)	24			(2		)	(8		)
Taxes payable							2			(12		)
Accrued interest	22			13			18			13
Other	(15		)	(10		)	(10		)	(1		)
Other operating activities
Defined benefit plans - funding	(6		)	(59		)	(4		)	—
Expenditures for asset retirement obligations	(22		)	(17		)	(4		)	(4		)
Other assets	(1		)	—			(1		)	—
Other liabilities	10			—			1			—
Net cash provided by operating activities	417			410			171			157
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(323		)	(420		)	(117		)	(117		)
Net cash used in investing activities	(323		)	(420		)	(117		)	(117		)
Cash Flows from Financing Activities
Issuance of long-term debt	399			100
Retirement of long-term debt	(200		)	—
Acquisition of outstanding bonds	(40		)	—
Remarketing of reacquired bonds	40			—
Net increase in notes payable with affiliates							21			—
Net decrease in short-term debt	(180		)	(23		)	(79		)	(10		)
Payment of common stock dividends to parent	(130		)	(113		)	(29		)	(30		)
Contributions from parent	25			43			25			—
Other financing activities	(6		)	(1		)	—			(1		)
Net cash provided by (used in) financing activities	(92		)	6
Net Increase (Decrease) in Cash and Cash Equivalents	2			(4		)
Net cash used in financing activities							(62		)	(41		)
Net Decrease in Cash and Cash Equivalents							(8		)	(1		)
Cash and Cash Equivalents at Beginning of Period	10			15			15			10
Cash and Cash Equivalents at End of Period	$	12		$	11		$	7		$	9

Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at September 30,	$	53		$	51
Accrued expenditures for property, plant and equipment at March 31,							$	39		$	37

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

Table of Contents

CONDENSED BALANCE SHEETS

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
Assets

Current Assets
Cash and cash equivalents	$	12	$	10	$	7	$	15
Accounts receivable (less reserve: 2019, $1; 2018, $1)
Accounts receivable (less reserve: 2020, $1; 2019, $1)
Customer	102		110		115		121
Other	42		30		40		41
Unbilled revenues	73		77
Unbilled revenues (less reserve: 2020, $0; 2019, $0)					65		76
Accounts receivable from affiliates	15		24		24		18
Fuel, materials and supplies	120		127		95		122
Prepayments	15		12		12		14
Regulatory assets	21		21		26		25
Other current assets					—		1
Total Current Assets	400		411		384		433

Property, Plant and Equipment
Regulated utility plant	6,052		5,816		6,469		6,372
Less: accumulated depreciation - regulated utility plant	823		741		881		846
Regulated utility plant, net	5,229		5,075		5,588		5,526
Construction work in progress	497		514		271		297
Property, Plant and Equipment, net	5,726		5,589		5,859		5,823

Other Noncurrent Assets
Regulatory assets	425		431		383		380
Goodwill	389		389		389		389
Other intangibles	43		47		40		41
Other noncurrent assets	44		16		70		67
Total Other Noncurrent Assets	901		883		882		877

Total Assets	$	7,027	$	6,883	$	7,125	$	7,133

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

Table of Contents

CONDENSED BALANCE SHEETS

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
Liabilities and Equity

Current Liabilities
Short-term debt	$	99	$	279	$	159	$	238
Long-term debt due within one year	—		434
Notes payable with affiliate					21		—
Accounts payable	169		172		141		172
Accounts payable to affiliates	21		26		27		31
Customer deposits	30		29		32		31
Taxes	29		26		35		33
Price risk management liabilities	5		4		4		4
Regulatory liabilities	12		17		1		2
Interest	33		11		33		15
Asset retirement obligations	29		23		24		24
Other current liabilities	39		39		40		47
Total Current Liabilities	466		1,060		517		597

Long-term Debt	2,004		1,375		2,005		2,005

Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	683		628		702		697
Investment tax credits	34		34		33		34
Price risk management liabilities	20		16		25		17
Asset retirement obligations	54		80		43		49
Regulatory liabilities	903		915		879		883
Other deferred credits and noncurrent liabilities	93		88		90		89
Total Deferred Credits and Other Noncurrent Liabilities	1,787		1,761		1,772		1,769

Commitments and Contingent Liabilities (Notes 7 and 11)
Commitments and Contingent Liabilities (Notes 7 and 10)

Stockholder's Equity
Common stock - no par value (a)	424		424		424		424
Additional paid-in capital	1,820		1,795		1,845		1,820
Earnings reinvested	526		468		562		518
Total Equity	2,770		2,687		2,831		2,762

Total Liabilities and Equity	$	7,027	$	6,883	$	7,125	$	7,133


(a)	75,000 shares authorized; 21,294 shares issued and outstanding at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018.~~2019.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

Table of Contents

CONDENSED STATEMENTS OF EQUITY

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars)


	Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Earnings reinvested			Total			Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Earnings reinvested			Total
June 30, 2019	21,294	$	424	$	1,820	$	505		$	2,749
December 31, 2019												21,294	$	424	$	1,820	$	518		$	2,762
Net income						80			80								73			73
Capital contributions from parent															25					25
Cash dividends declared on common stock						(59		)	(59		)						(29		)	(29		)
September 30, 2019	21,294	$	424	$	1,820	$	526		$	2,770
March 31, 2020												21,294	$	424	$	1,845	$	562		$	2,831

December 31, 2018	21,294	$	424	$	1,795	$	468		$	2,687		21,294	$	424	$	1,795	$	468		$	2,687
Net income						188			188								64			64
Capital contributions from parent				25					25
Cash dividends declared on common stock						(130		)	(130		)						(30		)	(30		)
September 30, 2019	21,294	$	424	$	1,820	$	526		$	2,770

June 30, 2018	21,294	$	424	$	1,755	$	432		$	2,611
Net income						66			66
Cash dividends declared on common stock						(32		)	(32		)
September 30, 2018	21,294	$	424	$	1,755	$	466		$	2,645

December 31, 2017	21,294	$	424	$	1,712	$	391		$	2,527
Net income						188			188
Capital contributions from parent				43					43
Cash dividends declared on common stock						(113		)	(113		)
September 30, 2018	21,294	$	424	$	1,755	$	466		$	2,645
March 31, 2019												21,294	$	424	$	1,795	$	502		$	2,721


(a)	Shares in thousands. All common shares of LG&E stock are owned by LKE.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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Table of Contents

CONDENSED STATEMENTS OF INCOME

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars)


	Three Months Ended September 30,				Nine Months Ended September 30,				Three Months Ended March 31,
	2019		2018		2019		2018		2020		2019
Operating Revenues
Retail and wholesale	$	464	$	445	$	1,316	$	1,322	$	432	$	448
Electric revenue from affiliate	2		2		6		10		—		2
Total Operating Revenues	466		447		1,322		1,332		432		450

Operating Expenses
Operation
Fuel	115		123		330		375		89		116
Energy purchases	5		5		15		14		5		5
Energy purchases from affiliate	2		5		21		21		14		13
Other operation and maintenance	107		114		320		331		104		108
Depreciation	83		70		233		208		84		72
Taxes, other than income	9		9		26		26		9		9
Total Operating Expenses	321		326		945		975		305		323

Operating Income	145		121		377		357		127		127

Other Income (Expense) - net	4		1		4		1		1		2

Interest Expense	28		24		82		74		28		26

Income Before Income Taxes	121		98		299		284		100		103

Income Taxes	26		21		62		59		20		22

Net Income (a)	$	95	$	77	$	237	$	225	$	80	$	81


(a)	Net income equals comprehensive income.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED STATEMENTS OF CASH FLOWS

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars)


	Nine Months Ended September 30,						Three Months Ended March 31,
	2019			2018			2020			2019
Cash Flows from Operating Activities
Net income	$	237		$	225		$	80		$	81
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	233			208			84			72
Amortization	7			2			3			3
Deferred income taxes and investment tax credits	44			37			4			15
Other	(3		)	(2		)	—			(1		)
Change in current assets and current liabilities
Accounts receivable							6			7
Accounts payable	(16		)	(2		)	(2		)	(16		)
Accounts payable to affiliates	(14		)	(8		)	(3		)	(1		)
Unbilled revenues	1			24			16			8
Fuel, materials and supplies	9			8			(3		)	(3		)
Regulatory assets and liabilities, net	(14		)	38			(12		)	(2		)
Taxes payable	5			11			6			(3		)
Accrued interest	28			21			25			22
Other	(6		)	(2		)	(4		)	9
Other operating activities
Defined benefit plans - funding	(3		)	(53		)	(1		)	—
Expenditures for asset retirement obligations	(45		)	(29		)	(11		)	(17		)
Other assets	(2		)	(1		)	3			(2		)
Other liabilities	10			8			2			2
Net cash provided by operating activities	471			485			193			174
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(436		)	(405		)	(138		)	(161		)
Other investing activities	—			1
Net increase in notes receivable with affiliates							(21		)	—
Net cash used in investing activities	(436		)	(404		)	(159		)	(161		)
Cash Flows from Financing Activities
Issuance of long-term debt	306			18
Retirement of long-term debt	—			(27		)
Net increase (decrease) in short-term debt	(233		)	83
Net decrease in short-term debt							(6		)	(2		)
Payment of common stock dividends to parent	(167		)	(196		)	(37		)	(39		)
Contributions from parent	68			45			37			28
Other financing activities	(5		)	(1		)	—			(1		)
Net cash used in financing activities	(31		)	(78		)	(6		)	(14		)
Net Increase in Cash and Cash Equivalents	4			3
Net Increase (Decrease) in Cash and Cash Equivalents							28			(1		)
Cash and Cash Equivalents at Beginning of Period	14			15			12			14
Cash and Cash Equivalents at End of Period	$	18		$	18		$	40		$	13

Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at September 30,	$	54		$	57
Accrued expenditures for property, plant and equipment at March 31,							$	39		$	51

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

Table of Contents

CONDENSED BALANCE SHEETS

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
Assets

Current Assets
Cash and cash equivalents	$	18	$	14	$	40	$	12
Accounts receivable (less reserve: 2019, $2; 2018, $2)
Accounts receivable (less reserve: 2020, $1; 2019, $1)
Customer	131		129		131		139
Other	27		34		22		27
Unbilled revenues	91		92
Unbilled revenues (less reserve: 2020, $0; 2019, $0)					72		88
Notes receivable from affiliate					21		—
Fuel, materials and supplies	113		121		131		128
Prepayments	16		11		10		14
Regulatory assets	6		4		26		16
Other current assets					—		1
Total Current Assets	402		405		453		425

Property, Plant and Equipment
Regulated utility plant	8,111		7,895		8,315		8,262
Less: accumulated depreciation - regulated utility plant	1,468		1,382		1,516		1,507
Regulated utility plant, net	6,643		6,513		6,799		6,755
Construction work in progress	535		503		522		496
Property, Plant and Equipment, net	7,178		7,016		7,321		7,251

Other Noncurrent Assets
Regulatory assets	426		418		384		386
Goodwill	607		607		607		607
Other intangibles	29		31		28		28
Other noncurrent assets	100		63		114		128
Total Other Noncurrent Assets	1,162		1,119		1,133		1,149

Total Assets	$	8,742	$	8,540	$	8,907	$	8,825

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

Table of Contents

CONDENSED BALANCE SHEETS

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars, shares in thousands)


	September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019
Liabilities and Equity

Current Liabilities
Short-term debt	$	2	$	235	$	144	$	150
Long-term debt due within one year	—		96		500		500
Accounts payable	120		171		96		121
Accounts payable to affiliates	40		53		50		52
Customer deposits	32		32		32		31
Taxes	29		24		32		26
Regulatory liabilities	19		31		15		17
Interest	44		16		45		20
Asset retirement obligations	63		59		42		46
Other current liabilities	47		35		44		51
Total Current Liabilities	396		752		1,000		1,014

Long-term Debt	2,623		2,225		2,124		2,123

Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	795		735		801		792
Investment tax credits	90		92		90		90
Asset retirement obligations	93		134		108		96
Regulatory liabilities	1,118		1,124		1,083		1,090
Other deferred credits and noncurrent liabilities	47		36		47		46
Total Deferred Credits and Other Noncurrent Liabilities	2,143		2,121		2,129		2,114

Commitments and Contingent Liabilities (Notes 7 and 11)
Commitments and Contingent Liabilities (Notes 7 and 10)

Stockholder's Equity
Common stock - no par value (a)	308		308		308		308
Additional paid-in capital	2,729		2,661		2,766		2,729
Earnings reinvested	543		473		580		537
Total Equity	3,580		3,442		3,654		3,574

Total Liabilities and Equity	$	8,742	$	8,540	$	8,907	$	8,825


(a)	80,000 shares authorized; 37,818 shares issued and outstanding at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018.~~2019.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

Table of Contents

CONDENSED STATEMENTS OF EQUITY

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars)


	Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Earnings reinvested			Total			Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Earnings reinvested			Total
June 30, 2019	37,818	$	308	$	2,729	$	524		$	3,561
December 31, 2019												37,818	$	308	$	2,729	$	537		$	3,574
Net income						95			95								80			80
Capital contributions from parent															37					37
Cash dividends declared on common stock						(76		)	(76		)						(37		)	(37		)
September 30, 2019	37,818	$	308	$	2,729	$	543		$	3,580
March 31, 2020												37,818	$	308	$	2,766	$	580		$	3,654

December 31, 2018	37,818	$	308	$	2,661	$	473		$	3,442		37,818	$	308	$	2,661	$	473		$	3,442
Net income						237			237								81			81
Capital contributions from parent				68					68						28					28
Cash dividends declared on common stock						(167		)	(167		)						(39		)	(39		)
September 30, 2019	37,818	$	308	$	2,729	$	543		$	3,580

June 30, 2018	37,818	$	308	$	2,661	$	445		$	3,414
Net income						77			77
Cash dividends declared on common stock						(60		)	(60		)
September 30, 2018	37,818	$	308	$	2,661	$	462		$	3,431

December 31, 2017	37,818	$	308	$	2,616	$	433		$	3,357
Net income						225			225
Capital contributions from parent				45					45
Cash dividends declared on common stock						(196		)	(196		)
September 30, 2018	37,818	$	308	$	2,661	$	462		$	3,431
March 31, 2019												37,818	$	308	$	2,689	$	515		$	3,512


(a)	Shares in thousands. All common shares of KU stock are owned by LKE.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

Table of Contents

Combined Notes to Condensed Financial Statements (Unaudited)

Index to Combined Notes to Condensed Financial Statements

The notes to the condensed financial statements that follow are a combined presentation. The following list indicates the Registrants to which the notes apply:

Registrant

PPL

PPL Electric

LKE

LG&E

1. Interim Financial Statements

2. Summary of Significant Accounting Policies

3. Segment and Related Information

4. Revenue from Contracts with Customers

5. Earnings Per Share

6. Income Taxes

7. Utility Rate Regulation

8. Financing Activities

9. ~~Leases~~

~~10.~~ Defined Benefits

~~11.~~10. Commitments and Contingencies

~~12.~~11. Related Party Transactions

~~13.~~12. Other Income (Expense) - net

~~14.~~13. Fair Value Measurements

~~15.~~14. Derivative Instruments and Hedging Activities

~~16.~~15. Asset Retirement Obligations

~~17.~~16. Accumulated Other Comprehensive Income (Loss)

~~18. New Accounting Guidance Pending Adoption~~

1. Interim Financial Statements

(All Registrants)

Capitalized terms and abbreviations appearing in the unaudited combined notes to condensed financial statements are defined in the glossary. Dollars are in millions, except per share data, unless otherwise noted. The specific Registrant to which disclosures are applicable is identified in parenthetical headings in italics above the applicable disclosure or within the applicable disclosure for each Registrants' related activities and disclosures. Within combined disclosures, amounts are disclosed for any Registrant when significant.

The accompanying unaudited condensed financial statements have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X and, therefore, do not include all of the information and footnote disclosures required by GAAP for complete financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation in accordance with GAAP are reflected in the condensed financial statements. All adjustments are of a normal recurring nature, except as otherwise disclosed. Each Registrant's Balance Sheet at December 31, ~~2018~~2019 is derived from that Registrant's ~~2018~~2019 audited Balance Sheet. The financial statements and notes thereto should be read in conjunction with the financial statements and notes contained in each Registrant's ~~2018~~2019 Form 10-K. The results of operations for the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 are not necessarily indicative of the results to be expected for the full year ending December 31, ~~2019~~2020 or other future periods, because results for interim periods can be disproportionately influenced by various factors, developments and seasonal variations.

~~Table of Contents~~

2. Summary of Significant Accounting Policies

(All Registrants)

The following accounting policy disclosures represent updates to Note 1 in each Registrant's ~~2018~~2019 Form 10-K and should be read in conjunction with those disclosures.

Table of Contents

Restricted Cash and Cash Equivalents (PPL and PPL Electric)

Reconciliation of Cash, Cash Equivalents and Restricted Cash

The following provides a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the Balance Sheets that sum to the total of the same amounts shown on the Statements of Cash Flows:


	PPL				PPL Electric				PPL				PPL Electric
	September 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019		March 31, 2020		December 31, 2019
Cash and cash equivalents	$	670	$	621	$	27	$	267	$	915	$	815	$	33	$	262
Restricted cash - current (a)	3		3		2		2		3		3		2		2
Restricted cash - noncurrent (a)	17		19		—		—		18		18		—		—
Total Cash, Cash Equivalents and Restricted Cash	$	690	$	643	$	29	$	269	$	936	$	836	$	35	$	264


(a)	Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash. On the Balance Sheets, the current portion of restricted cash is included in "Other current assets," while the noncurrent portion is included in "Other noncurrent assets."

~~New Accounting Guidance Adopted~~Current Expected Credit Losses(All Registrants)

Financing receivable collectibility is evaluated using a combination of factors, including past due status based on contractual terms, trends in write-offs and the age of the receivable. Specific events, such as bankruptcies, are also considered when applicable. Adjustments to the reserve for credit losses are made when necessary based on the results of analysis, the aging of receivables and historical and industry trends. The Registrants periodically evaluate the impact of observable external factors on the collectibility of the financing receivables to determine if adjustments to the reserve for credit losses should be made based on current conditions or reasonable and supportable forecasts.

Accounts receivable are written off in the period in which the receivable is deemed uncollectible.

(PPL and PPL Electric)

PPL Electric has identified one class of financing receivables, “accounts receivable-customer”, which includes financing receivables for all billed and unbilled sales with residential and non-residential customers. All other financing receivables are classified as other. Within the credit loss model for the residential customer accounts receivables, customers are disaggregated based on their projected propensity to pay, which is derived from historical trends and the current activity of the individual customer accounts. Conversely, the non-residential customer accounts receivables are not further segmented due to the varying nature of the individual customers, which lack readily identifiable risk characteristics for disaggregation.

(PPL, LKE, LG&E and KU)

LKE, LG&E and KU have identified one class of financing receivables, “accounts receivable-customer”, which includes financing receivables for all billed and unbilled sales with customers. All other financing receivables are classified as other.

(All Registrants)

~~Accounting for Leases~~

Effective January 1, 2019, the Registrants adopted accounting guidance that requires lessees to recognize a right-of-use asset and lease liability for leases, unless determined to meet the definition of a short-term lease. For income statement purposes, the FASB retained a dual model for lessees, requiring leases to be classified as either operating or finance. Operating leases result in straight-line expense recognition. Currently, all Registrant leases are operating leases.

Lessor accounting under the new guidance is similar to the current model, but updated to align with certain changes to the lessee model and current revenue recognition guidance. Lessors classify leases as operating, direct financing, or sales-type.

~~In adopting this new guidance, the Registrants elected to use the following practical expedients:~~

~~The Registrants did not re-assess the lease classifications or initial direct costs of existing leases. The Registrants also did not re-assess existing contracts for leases or lease classification.~~

The Registrants did not evaluate land easements that were not previously accounted for as leases under the new guidance. New land easements are evaluated under the new guidance beginning January 1, 2019.

~~See Note 9 for the required disclosures resulting from the adoption of the new guidance.~~

~~(PPL, LKE, LG&E & KU)~~

The following table shows changes in the amounts recorded on the Balance Sheets as of January 1, 2019 as a result of the adoption of the new lease guidance using a modified retrospective transition method with transition applied as of the beginning ofallowance for credit losses for the period ~~of adoption:~~ended March 31, 2020:




	Balance at Beginning of Period (a)		Charged to Income		Deductions (b)		Balance at End of Period
PPL
Accounts Receivable - Customer and Unbilled Revenue	$	30	$	9	$	5	$	34
Other (c)	27		—		1		26

PPL Electric
Accounts Receivable - Customer and Unbilled Revenue	$	25	$	5	$	2	$	28
Other	1		—		—		1

Table of Contents

PPL LKE LG&E KU
Right-of-Use Asset (a) $ 81
$ 56
$ 23
$ 31
Lease Liability- Current (b) 23
18
9
9
Lease Liability- Noncurrent (c) 67
46
18
26




	Balance at Beginning of Period (a)		Charged to Income		Deductions (b)		Balance at End of Period
LKE
Accounts Receivable - Customer and Unbilled Revenue	$	2	$	2	$	2	$	2
Other (c)	26		—		1		25

LG&E
Accounts Receivable - Customer and Unbilled Revenue	$	1	$	1	$	1	$	1

KU
Accounts Receivable - Customer and Unbilled Revenue	$	1	$	1	$	1	$	1


(a)	~~Right-of-Use Assets are recorded in "Other noncurrent assets" on the Balance Sheets.~~Reflects cumulative-effect adjustment upon adoption of current expected credit loss guidance.


(b)	~~Current lease liabilities are recorded in "Other current liabilities" on the Balance Sheets.~~Primarily related to uncollectible accounts receivable written off.


(c)	~~Noncurrent lease liabilities~~Primarily related to receivables at WKE, which are ~~recorded in "Other deferred credits and noncurrent liabilities" on the Balance Sheets.~~fully reserved.

(PPL, LKE, LGE and KU)

Asset Impairment (Excluding Investments)

PPL, LKE, LG&E and KU review goodwill for impairment at the reporting unit level annually or more frequently when events or circumstances indicate that the carrying amount of a reporting unit may be greater than the unit's fair value. PPL's, LKE's, LG&E's and KU's reporting units are primarily at the operating segment level.

PPL, LKE, LG&E and KU considered whether the economic events associated with COVID-19, which resulted in PPL’s shares experiencing volatility and a decrease in market value, would more likely than not reduce the fair value of the Registrants’ reporting units below their carrying amounts. See "Risks and Uncertainties" in Note 10 for additional information about COVID-19. Based on our assessment, a quantitative impairment test was not required for the LKE, LG&E and KU reporting units, but was required for the U.K. Regulated segment reporting unit, the allocated goodwill of which was $2.5 billion at March 31, 2020.The test did not indicate impairment of the reporting unit.

Although goodwill was not determined to be impaired at March 31, 2020, it is possible that an impairment charge could occur in future periods if PPL’s share price or any of the assumptions used in determining fair value of the reporting units are negatively impacted.

New Accounting Guidance Adopted

(All Registrants)

~~Improvements to~~ Accounting for ~~Hedging Activities~~Financial Instrument Credit Losses

Effective January 1, ~~2019,~~2020, the Registrants adopted accounting guidance, using a modified retrospective approach, ~~which reduces complexity when applying hedge accounting as well as improves~~that requires the ~~transparency~~use of ~~an entity's risk management activities. This guidance eliminates the separate measurement and reporting of hedge ineffectiveness for cash flow and net investment hedges and provides~~a current expected credit loss (CECL) model for the ~~ability~~measurement of credit losses on financial instruments within the scope of the guidance, which includes accounts receivable. The CECL model requires an entity to ~~perform subsequent qualitative effectiveness assessments.~~measure credit losses using historical information, current information and reasonable and supportable forecasts of future events, rather than the incurred loss impairment model required under previous GAAP. The adoption of this guidance did not have a material impact on the Registrants.

Accounting for Implementation Costs in a Cloud Computing Service Arrangement

Effective January 1, 2020, the Registrants prospectively adopted accounting guidance that requires a customer in a cloud computing hosting arrangement that is a service contract to capitalize implementation costs consistent with internal-use software guidance for non-service arrangements. The guidance requires these capitalized implementation costs to be amortized over the term of the hosting arrangement to the statement of income line item where the service arrangement costs are recorded. The guidance also ~~allows entities to apply~~prescribes the short-cut method to partial-term fair value hedges of interest rate risk as well as expands the ability to apply the critical terms match method to cash flow hedges of groups of forecasted transactions.

~~See Note 15 for the additional disclosures~~financial statement classification of the ~~income statement impacts of hedging activities required from~~capitalized implementation costs and cash flows associated with the arrangement. The adoption of this ~~guidance. Disclosures related to ineffectiveness are no longer required. Other impacts~~guidance did not have a material impact on the Registrants.

Table of ~~adopting~~Contents

(PPL, LKE, LG&E and KU)

Simplifying the Test for Goodwill Impairment

Effective January 1, 2020, the Registrants adopted accounting guidance that simplifies the test for goodwill impairment by eliminating the second step of the quantitative test. The second step of the quantitative test required a calculation of the implied fair value of goodwill, which was determined in the same manner as the amount of goodwill in a business combination. Under the new guidance, the fair value of a reporting unit will be compared with the carrying value and an impairment charge will be recognized if the carrying amount exceeds the fair value of the reporting unit. The adoption of this guidance ~~were~~did not ~~material.~~have a material impact on the Registrants.

3. Segment and Related Information

(PPL)

See Note 2 in PPL's ~~2018~~2019 Form 10-K for a discussion of reportable segments and related information.

Income Statement data for the segments and reconciliation to PPL's consolidated results for the ~~periods~~period ended ~~September 30~~March 31 are as follows:


	Three Months						Nine Months						Three Months
	2019			2018			2019			2018			2020			2019
Operating Revenues from external customers
U.K. Regulated	$	491		$	517		$	1,615		$	1,716		$	614		$	583
Kentucky Regulated	844			802			2,421			2,417			825			845
Pennsylvania Regulated	590			548			1,756			1,704			608			645
Corporate and Other	8			5			23			9			7			6
Total	$	1,933		$	1,872		$	5,815		$	5,846		$	2,054		$	2,079

Net Income
U.K. Regulated (a)	$	236		$	245		$	784		$	836		$	340		$	264
Kentucky Regulated	150			122			364			332			127			117
Pennsylvania Regulated	118			112			333			335			118			121
Corporate and Other	(29		)	(34		)	(99		)	(91		)	(31		)	(36		)
Total	$	475		$	445		$	1,382		$	1,412		$	554		$	466


(a)	Includes unrealized gains and losses from hedging foreign currency economic activity. See Note 1514 for additional information.

The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated Balance Sheets as of:

~~Table of Contents~~


	September 30, 2019			December 31, 2018		March 31, 2020		December 31, 2019
Assets
U.K. Regulated (a) (b)	$	17,128		$	16,700	$	17,918	$	17,622
Kentucky Regulated	15,434			15,078		15,608		15,597
Pennsylvania Regulated	12,116			11,257		11,898		11,918
Corporate and Other (c)	(119		)	361		904		543
Total	$	44,559		$	43,396	$	46,328	$	45,680


(a)	Includes ~~$12.3~~$13.3 billion and ~~$12.4~~$13.2 billion of net PP&E as of ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018.~~2019. WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP.


(b)	Includes ~~$2.3 billion and $2.4~~$2.5 billion of goodwill as of ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018. The change is due to the effect of foreign currency exchange rates.~~2019.


(c)	Primarily consists of unallocated items, including cash, PP&E, goodwill, the elimination of inter-segment transactions as well as the assets of Safari Energy.

(PPL Electric, LKE, LG&E and KU)

PPL Electric has 2 operating segments, distribution and transmission, which are aggregated into a single reportable segment. LKE, LG&E and KU are individually single operating and reportable segments.

Table of Contents

4. Revenue from Contracts with Customers

(All Registrants)

See Note 3 in PPL's ~~2018~~2019 Form 10-K for a discussion of the principal activities from which the Registrants and PPL’s segments generate their revenues.

The following tables reconcile "Operating Revenues" included in each Registrant's Statement of Income with revenues generated from contracts with customers for the ~~periods~~period ended ~~September 30.~~March 31.


	2019 Three Months															2020 Three Months
	PPL			PPL Electric			LKE			LG&E			KU			PPL			PPL Electric			LKE			LG&E			KU
Operating Revenues (a)	$	1,933		$	590		$	844		$	382		$	466		$	2,054		$	608		$	825		$	407		$	432
Revenues derived from:
Alternative revenue programs (b)	8			2			6			4			2			(3		)	—			(3		)	(3		)	—
Other (c)	(11		)	(3		)	(6		)	(3		)	(3		)	(10		)	(2		)	(6		)	(3		)	(3		)
Revenues from Contracts with Customers	$	1,930		$	589		$	844		$	383		$	465		$	2,041		$	606		$	816		$	401		$	429

	2018 Three Months
	PPL			PPL Electric			LKE			LG&E			KU
Operating Revenues (a)	$	1,872		$	548		$	802		$	362		$	447
Revenues derived from:
Alternative revenue programs (b)	(4		)	(3		)	(1		)	(4		)	3
Other (c)	(15		)	(3		)	(5		)	(2		)	(3		)
Revenues from Contracts with Customers	$	1,853		$	542		$	796		$	356		$	447

2019 Nine Months
PPL PPL Electric LKE LG&E KU
Operating Revenues (a) $ 5,815
$ 1,756
$ 2,421
$ 1,126
$ 1,322
Revenues derived from:

Alternative revenue programs (b) (18 ) (4 ) (14 ) (1 ) (13 )
Other (c) (30 ) (8 ) (16 ) (7 ) (9 )
Revenues from Contracts with Customers $ 5,767
$ 1,744
$ 2,391
$ 1,118
$ 1,300

~~Table of Contents~~


	2018 Nine Months															2019 Three Months
	PPL			PPL Electric			LKE			LG&E			KU			PPL			PPL Electric			LKE			LG&E			KU
Operating Revenues (a)	$	5,846		$	1,704		$	2,417		$	1,116		$	1,332		$	2,079		$	645		$	845		$	410		$	450
Revenues derived from:
Alternative revenue programs (b)	37			(1		)	38			16			22			(6		)	(4		)	(2		)	(2		)	—
Other (c)	(43		)	(9		)	(14		)	(5		)	(9		)	(10		)	(3		)	(4		)	(1		)	(3		)
Revenues from Contracts with Customers	$	5,840		$	1,694		$	2,441		$	1,127		$	1,345		$	2,063		$	638		$	839		$	407		$	447

(a)

PPL includes ~~$491~~$614 million and ~~$1,615~~$583 million ~~for the three and nine months ended September 30, 2019 and $517 million and $1,716 million for the three and nine months ended September 30, 2018~~ of revenues from external customers reported by the U.K. Regulated ~~segment.~~segment for the three months ended March 31, 2020 and 2019. PPL Electric and LKE represent revenues from external customers reported by the Pennsylvania Regulated and Kentucky Regulated segments. See Note 3 for additional information.


(b)	Alternative revenue programs include the transmission formula rate for PPL Electric, the ECR and DSM programs for LG&E and KU, the GLT program for LG&E, and the generation formula rate for KU. This line item shows the over/under collection of these rate mechanisms with over-collections of revenue shown as positive amounts in the table above and under-collections shown as negative amounts.


(c)	Represents additional revenues outside the scope of revenues from contracts with customers, such as leases and other miscellaneous revenues.

As discussed in Note 2 in PPL's 2018 Form 10-K, PPL's segments are segmented by geographic location. Revenues from external customers for each segment/geographic location are reconciled to revenues from contracts with customers in the footnotes to the tables above.

The following tables show revenues from contracts with customers disaggregated by customer class for the periods ended ~~September 30.~~March 31.

2019 Three Months
PPL PPL Electric LKE LG&E KU
Licensed energy suppliers (a) $ 454
$ —
$ —
$ —
$ —
Residential 708
352
356
177
179
Commercial 346
97
249
123
126
Industrial 164
16
148
47
101
Other (b) 128
12
73
31
42
Wholesale - municipality 6
—
6
—
6
Wholesale - other (c) 12
—
12
5
11
Transmission 112
112
—
—
—
Revenues from Contracts with Customers $ 1,930
$ 589
$ 844
$ 383
$ 465

2018 Three Months
PPL PPL Electric LKE LG&E KU
Licensed energy suppliers (a) $ 475
$ —
$ —
$ —
$ —
Residential 647
328
319
162
157
Commercial 307
88
219
112
107
Industrial 156
12
144
45
99
Other (b) 119
14
65
27
39
Wholesale - municipality 30
—
30
—
30
Wholesale - other (c) 19
—
19
10
15
Transmission 100
100
—
—
—
Revenues from Contracts with Customers $ 1,853
$ 542
$ 796
$ 356
$ 447



	2020 Three Months
	PPL (d)		PPL Electric (d)		LKE		LG&E		KU
Licensed energy suppliers (a)	$	583	$	—	$	—	$	—	$	—
Residential	714		344		370		187		183
Commercial	312		81		231		124		107
Industrial	144		8		136		45		91
Other (b)	116		14		66		28		38
Wholesale - municipality	5		—		5		—		5
Wholesale - other (c)	8		—		8		17		5
Transmission	159		159		—		—		—
Revenues from Contracts with Customers	$	2,041	$	606	$	816	$	401	$	429

Table of Contents


	2019 Nine Months										2019 Three Months
	PPL		PPL Electric		LKE		LG&E		KU		PPL		PPL Electric		LKE		LG&E		KU
Licensed energy suppliers (a)	$	1,520	$	—	$	—	$	—	$	—	$	556	$	—	$	—	$	—	$	—
Residential	2,058		1,060		998		504		494		778		407		371		189		182
Commercial	967		279		688		352		336		319		95		224		121		103
Industrial	470		48		422		134		288		150		17		133		44		89
Other (b)	360		39		209		93		116		114		14		70		33		37
Wholesale - municipality	38		—		38		—		38		28		—		28		—		28
Wholesale - other (c)	36		—		36		35		28		13		—		13		20		8
Transmission	318		318		—		—		—		105		105		—		—		—
Revenues from Contracts with Customers	$	5,767	$	1,744	$	2,391	$	1,118	$	1,300	$	2,063	$	638	$	839	$	407	$	447

	2018 Nine Months
	PPL		PPL Electric		LKE		LG&E		KU
Licensed energy suppliers (a)	$	1,606	$	—	$	—	$	—	$	—
Residential	2,039		1,036		1,003		505		498
Commercial	928		275		653		343		310
Industrial	466		37		429		134		295
Other (b)	339		40		200		88		113
Wholesale - municipality	91		—		91		—		91
Wholesale - other (c)	65		—		65		57		38
Transmission	306		306		—		—		—
Revenues from Contracts with Customers	$	5,840	$	1,694	$	2,441	$	1,127	$	1,345


(a)	Represents customers of WPD.


(b)	Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses.


(c)	Includes wholesale power and transmission revenues. LG&E and KU amounts include intercompany power sales and transmission revenues, which are eliminated upon consolidation at LKE.


(d)	In the fourth quarter of 2019, management deemed it appropriate to present the revenue offset associated with network integration transmission service (NITS) as distribution revenue rather than transmission revenue.

As discussed in Note 2 in PPL's 2019 Form 10-K, PPL segments its business by geographic location. Revenues from external customers for each segment/geographic location are reconciled to revenues from contracts with customers in the footnotes to the tables above. PPL Electric's revenues from contracts with customers are further disaggregated by distribution and transmission, which were ~~$477~~$447 million and ~~$112~~$159 million for the three months ended ~~September 30, 2019~~March 31, 2020 and ~~$1.4 billion and $318 million for the nine months ended September 30, 2019. PPL Electric's revenue from contracts with customers disaggregated by distribution and transmission were $442~~$533 million and ~~$100~~$105 million for the three months ended ~~September 30, 2018 and $1.4 billion and $306 million for the nine months ended September 30, 2018.~~March 31, 2019.

Contract receivables from customers are primarily included in "Accounts receivable - Customer" and "Unbilled revenues" on the Balance Sheets.

The following table shows the accounts receivable and unbilled revenues balances that were impaired for the ~~periods~~period ended ~~September 30.~~March 31.


	Three Months				Nine Months				Three Months
	2019		2018		2019		2018		2020		2019
PPL	$	11	$	11	$	22	$	24	$	8	$	9
PPL Electric	8		7		14		17		4		6
LKE	2		4		5		7		2		2
LG&E	1		2		2		3		1		1
KU	1		2		3		4		1		1

The following table shows the balances and certain activity of contract liabilities resulting from contracts with customers.

~~Table of Contents~~

PPL PPL Electric LKE LG&E KU
Contract liabilities at December 31, 2018 $ 42
$ 23
$ 9
$ 5
$ 4
Contract liabilities at September 30, 2019 42
19
9
5
4
Revenue recognized during the nine months ended September 30, 2019 that was included in the contract liability balance at December 31, 2018 31
11
9
5
4

Contract liabilities at December 31, 2017 $ 29
$ 19
$ 8
$ 4
$ 4
Contract liabilities at September 30, 2018 40
17
8
4
4
Revenue recognized during the nine months ended September 30, 2018 that was included in the contract liability balance at December 31, 2017 22
8
8
4
4



	PPL		PPL Electric		LKE		LG&E		KU
Contract liabilities at December 31, 2019	$	44	$	21	$	9	$	5	$	4
Contract liabilities at March 31, 2020	42		15		14		10		4
Revenue recognized during the three months ended March 31, 2020 that was included in the contract liability balance at December 31, 2019	23		8		9		5		4

Contract liabilities at December 31, 2018	$	42	$	23	$	9	$	5	$	4
Contract liabilities at March 31, 2019	37		14		7		4		3
Revenue recognized during the three months ended March 31, 2019 that was included in the contract liability balance at December 31, 2018	25		11		9		5		4

Contract liabilities result from recording contractual billings in advance for customer attachments to the Registrants' infrastructure and payments received in excess of revenues earned to date. Advanced billings for customer attachments are recognized as revenue ratably over the billing period. Payments received in excess of revenues earned to date are recognized as revenue as services are delivered in subsequent periods.

Table of Contents

At ~~September 30, 2019,~~March 31, 2020, PPL had ~~$48~~$32 million of performance obligations attributable to Corporate and Other that have not been satisfied. Of this amount, PPL expects to recognize approximately ~~$41~~$28 million within the next 12 months.

5. Earnings Per Share

(PPL)

Basic EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding during the applicable period. Diluted EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding, increased by incremental shares that would be outstanding if potentially dilutive non-participating securities were converted to common shares as calculated using the Treasury Stock Method. Incremental non-participating securities that have a dilutive impact are detailed in the table below. These dilutive securities ~~also~~ include the PPL common stock forward sale agreements, ~~entered into~~which were settled in ~~May 2018. See Note 8 in PPL's 2018 Form 10-K for additional information on these agreements.~~2019. The forward sale agreements ~~are~~were dilutive under the Treasury Stock Method to the extent the average stock price of PPL's common shares ~~exceeds~~exceeded the forward sale price prescribed in the agreements.

Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the ~~periods~~period ended ~~September 30~~March 31 used in the EPS calculation are:

Three Months Nine Months
2019 2018 2019 2018
Income (Numerator)

Net income $ 475
$ 445
$ 1,382
$ 1,412
Less amounts allocated to participating securities —
1
2
2
Net income available to PPL common shareowners - Basic and Diluted $ 475
$ 444
$ 1,380
$ 1,410

Shares of Common Stock (Denominator)

Weighted-average shares - Basic EPS 722,259
703,730
721,693
699,117
Add incremental non-participating securities:

Share-based payment awards 1,106
298
1,009
427
Forward sale agreements 7,786
6,489
7,975
2,761
Weighted-average shares - Diluted EPS 731,151
710,517
730,677
702,305

Basic EPS

Net Income available to PPL common shareowners $ 0.66
$ 0.63
$ 1.91
$ 2.02

Diluted EPS

Net Income available to PPL common shareowners $ 0.65
$ 0.62
$ 1.89
$ 2.01

~~Table of Contents~~



	Three Months
	2020		2019
Income (Numerator)
Net income	$	554	$	466
Less amounts allocated to participating securities	1		—
Net income available to PPL common shareowners - Basic and Diluted	$	553	$	466

Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS	767,948		721,023
Add incremental non-participating securities:
Share-based payment awards	790		1,023
Forward sale agreements	—		7,907
Weighted-average shares - Diluted EPS	768,738		729,953

Basic EPS
Net Income available to PPL common shareowners	$	0.72	$	0.65

Diluted EPS
Net Income available to PPL common shareowners	$	0.72	$	0.64

For the ~~periods~~period ended ~~September 30,~~March 31, PPL issued common stock related to stock-based compensation plans and the DRIP as follows (in thousands):



	Three Months
	2020	2019
Stock-based compensation plans	598	590
DRIP	434	458

Three Months Nine Months
2019 2018 2019 2018
Stock-based compensation plans (a) 38
80
680
568
DRIP 430
493
1,305
1,504


~~(a)~~	~~Includes stock options exercised, vesting of performance units, vesting of restricted stock units and conversion of stock units granted to directors.~~

For the ~~periods~~period ended ~~September 30,~~March 31, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive.

Three Months Nine Months
2019 2018 2019 2018
Stock options —
15
—
229
Restricted stock units —
2
—
15



	Three Months
	2020	2019
Stock-based compensation awards	250	—

Table of Contents

6. Income Taxes

Reconciliations of income ~~taxes~~tax expense (benefit) for the ~~periods~~period ended ~~September 30~~March 31 are as follows.

																			(PPL)
	Three Months						Nine Months						Three Months
	2019			2018			2019			2018			2020			2019
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	125		$	115		$	359		$	373		$	146		$	124
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	13			9			34			34			13			13
Valuation allowance adjustments ~~(a)~~	7			5			21			17			6			7
Impact of lower U.K. income tax rates	(6		)	(7		)	(20		)	(20		)	(11		)	(8		)
Impact of the U.K. Finance Act on deferred tax balances	(5		)	(4		)	(8		)	(7		)
Depreciation and other items not normalized	(2		)	(1		)	(5		)	(4		)
Amortization of excess deferred federal and state income taxes	(9		)	(11		)	(30		)	(30		)	(11		)	(11		)
Deferred tax impact of state tax reform (b)	—			—			—			9
Interest benefit on U.K. financing entities	(3		)	(4		)	(9		)	(13		)
Kentucky recycling credit, net of federal income tax expense (a)	—			—			(20		)	—
Other	(2		)	1			6			3			(3		)	1
Total increase (decrease)	(7		)	(12		)	(31		)	(11		)	(6		)	2
Total income taxes	$	118		$	103		$	328		$	362
Total income tax expense (benefit)													$	140		$	126



(PPL Electric)
	Three Months
	2020			2019
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	33		$	34
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	13			13
Amortization of excess deferred income taxes	(3		)	(4		)
Other	(2		)	(1		)
Total increase (decrease)	8			8
Total income tax expense (benefit)	$	41		$	42

~~(a)~~

During the second quarter of 2019, LKE recorded a deferred income tax benefit associated with two projects placed into service that prepare a generation waste material for reuse and, as a result, qualify for a Kentucky recycling credit. The applicable credit provides tax benefits for a portion of the equipment costs for major recycling projects in Kentucky, with the benefit recognized during the period in which the assets are placed into service. A valuation allowance of $3 million has been recognized related to this credit due to insufficient Kentucky taxable income projected at LKE. During the third quarter of 2019, LKE filed the Kentucky recycling credit application with the Kentucky Department of Revenue and expects a ruling in the fourth quarter of 2019.


~~(b)~~	During the second quarter of 2018, LKE recorded deferred income tax expense, primarily associated with LKE's non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018.



(LKE)
	Three Months
	2020			2019
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	35		$	33
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	7			6
Amortization of excess deferred federal and state income taxes	(7		)	(6		)
Other	(1		)	(1		)
Total increase (decrease)	(1		)	(1		)
Total income tax expense (benefit)	$	34		$	32



(LG&E)
	Three Months
	2020			2019
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	19		$	17
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	4			3
Amortization of excess deferred federal and state income taxes	(3		)	(3		)
Other	(1		)	—
Total increase (decrease)	—			—
Total income tax expense (benefit)	$	19		$	17

Table of Contents


(PPL Electric)
(KU)
	Three Months						Nine Months						Three Months
	2019			2018			2019			2018			2020			2019
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	33		$	30		$	94		$	93		$	21		$	22
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	13			12			36			35			4			4
Depreciation and other items not normalized	(2		)	(1		)	(5		)	(4		)
Amortization of excess deferred income taxes	(4		)	(5		)	(12		)	(13		)
Amortization of excess deferred federal and state income taxes													(4		)	(3		)
Other	—			(1		)	1			—			(1		)	(1		)
Total increase (decrease)	7			5			20			18			(1		)	—
Total income taxes	$	40		$	35		$	114		$	111
Total income tax expense (benefit)													$	20		$	22

(LKE)
Three Months Nine Months
2019 2018 2019 2018
Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 42
$ 34
$ 98
$ 97
Increase (decrease) due to:

State income taxes, net of federal income tax benefit 8
6
18
17
Amortization of investment tax credit (1 ) (1 ) (2 ) (3 )
Deferred tax impact of U.S tax reform —
(2 ) —
(2 )
Deferred tax impact of state tax reform (a) —
—
—
9
Valuation allowance adjustments (b) —
—
3
—
Amortization of excess deferred federal and state income taxes (5 ) (3 ) (17 ) (14 )
Kentucky recycling credit, net of federal income tax expense (b) —
—
(20 ) —
Other (1 ) (2 ) (2 ) (2 )
Total increase (decrease) 1
(2 ) (20 ) 5
Total income taxes $ 43
$ 32
$ 78
$ 102


~~(a)~~	During the second quarter of 2018, LKE recorded deferred income tax expense, primarily associated with LKE's non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018.

~~(b)~~

During the second quarter of 2019, LKE recorded a deferred income tax benefit associated with two projects placed into service that prepare a generation waste material for reuse and, as a result, qualify for a Kentucky recycling credit. The applicable credit provides tax benefits for a portion of the equipment costs for major recycling projects in Kentucky, with the benefit recognized during the period in which the assets are placed into service. A portion of this amount has been reserved due to insufficient Kentucky taxable income projected at LKE. During the third quarter of 2019, LKE filed the Kentucky recycling credit application with the Kentucky Department of Revenue and expects a ruling in the fourth quarter of 2019.

(LG&E)
Three Months Nine Months
2019 2018 2019 2018
Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 21
$ 18
$ 50
$ 50
Increase (decrease) due to:

State income taxes, net of federal income tax benefit 4
3
9
9
Valuation allowance adjustments (a) —
—
15
—
Amortization of excess deferred federal and state income taxes (2 ) (1 ) (7 ) (6 )
Kentucky recycling credit, net of federal income tax expense (a) —
—
(15 ) —
Other (1 ) (2 ) (1 ) (2 )
Total increase (decrease) 1
—
1
1
Total income taxes $ 22
$ 18
$ 51
$ 51

~~(a)~~

During the second quarter of 2019, LG&E recorded a deferred income tax benefit associated with two projects placed into service that prepare a generation waste material for reuse and, as a result, qualify for a Kentucky recycling credit. The applicable credit provides tax benefits for a portion of the equipment costs for major recycling projects in Kentucky, with the benefit recognized during the period in which the assets are placed into service. This amount has been reserved due to insufficient Kentucky taxable income projected at LG&E.

~~Table of Contents~~

(KU)
Three Months Nine Months
2019 2018 2019 2018
Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 25
$ 21
$ 63
$ 60
Increase (decrease) due to:

State income taxes, net of federal income tax benefit 5
3
12
10
Valuation allowance adjustments (a) —
—
5
—
Amortization of excess deferred federal and state income taxes (3 ) (2 ) (10 ) (8 )
Kentucky recycling credit, net of federal income tax expense (a) —
—
(5 ) —
Other (1 ) (1 ) (3 ) (3 )
Total increase (decrease) 1
—
(1 ) (1 )
Total income taxes $ 26
$ 21
$ 62
$ 59

~~(a)~~

During the second quarter of 2019, KU recorded a deferred income tax benefit associated with a project placed into service that prepares a generation waste material for reuse and, as a result, qualifies for a Kentucky recycling credit. The applicable credit provides tax benefits for a portion of the equipment costs for major recycling projects in Kentucky, with the benefit recognized during the period in which the assets are placed into service. This amount has been reserved due to insufficient Kentucky taxable income projected at KU.

Other

~~U.S. Tax Reform~~2020 TCJA Regulatory Update (All Registrants)

TheIRS issued proposed regulations for certain provisions of the TCJA in 2018, including rules relating to limitations on interest ~~deductibility and Global Intangible Low-Taxed Income (GILTI). In June 2019, the IRS issued both final and new~~deductibility. These proposed regulations relating to GILTI. PPL has determined that neither these final nor proposed regulations materially change PPL's current interpretation of the statutory impact of these rules on the Registrants. Proposed regulations relating to the limitation on the deductibility of interest expense were issued in November 2018 and ~~such regulations provide detailed rules implementing the broader statutory provisions. These proposed regulations~~ should not apply to the Registrants until the year in which the regulations are issued in final form, which is expected to be in ~~the fourth quarter of 2019.~~2020. It is uncertain what form the final regulations will take and, therefore, the Registrants cannot predict what impact the final regulations will have on the tax deductibility of interest expense. However, if the proposed regulations were issued as final in their current form, the Registrants could have a limitation on a portion of their interest expense deduction for tax purposes and such limitation could be significant. PPL expressed its views on these proposed regulations in a comment letter addressed to the IRS on February 26, 2019.

7. Utility Rate Regulation

(All Registrants)

The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations.


	PPL				PPL Electric				PPL				PPL Electric
	September 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019		March 31, 2020		December 31, 2019
Current Regulatory Assets:
Plant outage costs									$	44	$	32	$	—	$	—
Gas supply clause	$	10	$	12	$	—	$	—	5		8		—		—
Smart meter rider	13		11		13		11		15		13		15		13
Plant outage costs	17		10		—		—
Transmission formula rate									—		—		3		3
Transmission service charge	8		—		8		—		5		10		5		10
Other	1		3		1		—		6		4		—		—
Total current regulatory assets (a)	$	49	$	36	$	22	$	11	$	75	$	67	$	23	$	26

Noncurrent Regulatory Assets:
Defined benefit plans									$	788	$	800	$	460	$	467
Storm costs									34		39		12		15
Unamortized loss on debt									37		41		15		18
Interest rate swaps									29		22		—		—
Terminated interest rate swaps									80		81		—		—
Accumulated cost of removal of utility plant									222		220		222		220
AROs									282		279		—		—
Act 129 compliance rider									—		6		—		6
Other									5		4		1		—
Total noncurrent regulatory assets									$	1,477	$	1,492	$	710	$	726

Table of Contents

PPL PPL Electric
September 30,
2019 December 31,
2018 September 30,
2019 December 31,
2018
Noncurrent Regulatory Assets:

Defined benefit plans $ 937
$ 963
$ 553
$ 558
Storm costs 42
56
16
22
Unamortized loss on debt 41
45
17
22
Interest rate swaps 25
20
—
—
Terminated interest rate swaps 83
87
—
—
Accumulated cost of removal of utility plant 211
200
211
200
AROs 304
273
—
—
Act 129 compliance rider 10
19
10
19
Other 5
10
—
3
Total noncurrent regulatory assets $ 1,658
$ 1,673
$ 807
$ 824



	PPL				PPL Electric
	March 31, 2020		December 31, 2019		March 31, 2020		December 31, 2019
Current Regulatory Liabilities:
Generation supply charge	$	24	$	23	$	24	$	23
Environmental cost recovery	4		5		—		—
Universal service rider	5		9		5		9
Fuel adjustment clause	6		8		—		—
TCJA customer refund	46		61		46		59
Storm damage expense rider	8		5		8		5
Other	6		4		—		—
Total current regulatory liabilities	$	99	$	115	$	83	$	96

Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	640	$	640	$	—	$	—
Power purchase agreement - OVEC	49		51		—		—
Net deferred taxes	1,739		1,756		580		588
Defined benefit plans	53		51		13		11
Terminated interest rate swaps	68		68		—		—
Act 129 compliance rider	—		—		2		—
Other	8		6		—		—
Total noncurrent regulatory liabilities	$	2,557	$	2,572	$	595	$	599

PPL PPL Electric
September 30,
2019 December 31,
2018 September 30,
2019 December 31,
2018
Current Regulatory Liabilities:
Generation supply charge $ 22
$ 33
$ 22
$ 33
Environmental cost recovery 12
16
—
—
Universal service rider 12
27
12
27
Fuel adjustment clause 13
—
—
—
TCJA customer refund 8
20
7
3
Storm damage expense rider 7
5
7
5
Generation formula rate —
7
—
—
Other 5
14
—
6
Total current regulatory liabilities $ 79
$ 122
$ 48
$ 74

Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant $ 674
$ 674
$ —
$ —
Power purchase agreement - OVEC 53
59
—
—
Net deferred taxes 1,775
1,826
601
629
Defined benefit plans 54
37
10
5
Terminated interest rate swaps 69
72
—
—
TCJA customer refund (b) 43
41
43
41
Other 7
5
—
—
Total noncurrent regulatory liabilities $ 2,675
$ 2,714
$ 654
$ 675


	LKE				LG&E				KU				LKE				LG&E				KU
	September 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019		March 31, 2020		December 31, 2019		March 31, 2020		December 31, 2019
Current Regulatory Assets:
Plant outage costs	$	17	$	10	$	11	$	7	$	6	$	3	$	44	$	32	$	18	$	16	$	26	$	16
Gas supply clause	10		12		10		12		—		—		5		8		5		8		—		—
Other	—		3		—		2		—		1		3		1		3		1		—		—
Total current regulatory assets	$	27	$	25	$	21	$	21	$	6	$	4	$	52	$	41	$	26	$	25	$	26	$	16

Noncurrent Regulatory Assets:
Defined benefit plans													$	328	$	333	$	202	$	206	$	126	$	127
Storm costs													22		24		14		14		8		10
Unamortized loss on debt													22		23		13		14		9		9
Interest rate swaps													29		22		29		22		—		—
Terminated interest rate swaps													80		81		47		47		33		34
AROs													282		279		77		76		205		203
Other													4		4		1		1		3		3
Total noncurrent regulatory assets													$	767	$	766	$	383	$	380	$	384	$	386

Table of Contents

LKE LG&E KU
September 30,
2019 December 31,
2018 September 30,
2019 December 31,
2018 September 30,
2019 December 31,
2018
Noncurrent Regulatory Assets:
Defined benefit plans $ 384
$ 405
$ 233
$ 249
$ 151
$ 156
Storm costs 26
34
16
20
10
14
Unamortized loss on debt 24
23
14
15
10
8
Interest rate swaps 25
20
25
20
—
—
Terminated interest rate swaps 83
87
48
51
35
36
AROs 304
273
87
75
217
198
Other 5
7
2
1
3
6
Total noncurrent regulatory assets $ 851
$ 849
$ 425
$ 431
$ 426
$ 418


	LKE				LG&E				KU				LKE				LG&E				KU
	September 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018		September 30, 2019		December 31, 2018		March 31, 2020		December 31, 2019		March 31, 2020		December 31, 2019		March 31, 2020		December 31, 2019
Current Regulatory Liabilities:
Environmental cost recovery	$	12	$	16	$	7	$	6	$	5	$	10	$	4	$	5	$	—	$	1	$	4	$	4
Demand side management													2		3		1		1		1		2
Fuel adjustment clause	13		—		3		—		10		—		6		8		—		—		6		8
TCJA customer refund	1		17		—		7		1		10
Generation formula rate	—		7		—		—		—		7
Other	5		8		2		4		3		4		4		3		—		—		4		3
Total current regulatory liabilities	$	31	$	48	$	12	$	17	$	19	$	31	$	16	$	19	$	1	$	2	$	15	$	17

Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	674	$	674	$	279	$	279	$	395	$	395	$	640	$	640	$	267	$	266	$	373	$	374
Power purchase agreement - OVEC	53		59		37		41		16		18		49		51		34		35		15		16
Net deferred taxes	1,174		1,197		548		557		626		640		1,159		1,168		540		544		619		624
Defined benefit plans	44		32		1		—		43		32		40		40		—		—		40		40
Terminated interest rate swaps	69		72		34		36		35		36		68		68		34		34		34		34
Other	7		5		4		2		3		3		6		6		4		4		2		2
Total noncurrent regulatory liabilities	$	2,021	$	2,039	$	903	$	915	$	1,118	$	1,124	$	1,962	$	1,973	$	879	$	883	$	1,083	$	1,090


(a)	For PPL, these amounts are included in "Other current assets" on the Balance Sheets.

~~(b)~~

Relates to amounts owed to PPL Electric customers as a result of the reduced U.S. federal corporate income tax rate as enacted by the TCJA, for the period of January 1, 2018 through June 30, 2018 which is not yet reflected in distribution customer rates. The initial liability was recorded during the second quarter of 2018. A petition for the distribution method back to customers of this liability was proposed to the PUC on October 4, 2019. The petition is currently under review by the PUC and contingent upon PUC approval.

Regulatory Matters

Kentucky Activities

~~Rate Case Proceedings~~ ECR Filings ((PPL, LKE, LG&E and ~~KU)~~KU

In September 2018, LG&E and KU filed requests with the KPSC for an increase in annual base electricity rates of approximately $112 million at KU and increases in annual base electricity and gas rates of approximately $35 million and $25 million at LG&E. LG&E’s and KU’s applications also sought to include changes associated with the TCJA and state tax reform in the calculation of the proposed base rates and to terminate the TCJA bill credit mechanism when new base rates go into effect. The elimination of the TCJA bill credit mechanism will result in an estimated annual electricity revenue increase of approximately $58 million at KU and increases in electricity and gas revenues of approximately $40 million and $12 million at LG&E. The applications were based on a forecasted test year of May 1, 2019 through April 30, 2020 with a requested return-on-equity of 10.42%.)

On March ~~1, 2019,~~31, 2020, LG&E and KU ~~along with substantially all intervening parties~~submitted applications to the ~~proceeding, filed stipulation~~KPSC for ECR rate treatment regarding upcoming environmental construction projects relating to the EPA's regulations addressing ELGs. The construction projects are expected to begin in 2020 and ~~recommendation agreements (stipulations) with the KPSC resolving all material issues with the parties. In addition~~continue through 2024 and are estimated to

~~Table of Contents~~

~~terminating the TCJA bill credit mechanism, the proposed stipulations provided for increases in annual revenue requirements associated with base electricity rates of~~ cost approximately ~~$58~~$405 million ~~at KU and increases in annual base electricity and gas rates of approximately $4 million and $20~~($153 million at LG&E ~~based on a return-on-equity of 9.725%.~~

~~On April 30, 2019, the KPSC issued orders ruling on open issues~~ and ~~approving the proposed stipulations filed in March 2019. The orders provide for increases in the revenue requirements associated with base electricity rates of $56~~$252 million at KU and increases associated with base electricity and gas rates of $2 million and $19 million at LG&E. With the termination of the TCJA bill credit mechanism, this represents annual revenue increases of $187 million ($114 million at KU and $73 million at LG&E)KU). The ~~new base rates~~applications request an authorized 9.725% return on equity with respect to LG&E's and ~~all elements of~~KU's ECR mechanisms consistent with the ~~orders became effective~~2018 Kentucky rate cases approved in April 2019. Decisions on ~~May 1, 2019.~~

~~Pennsylvania Activities~~the applications are currently expected in September 2020.

~~PUC Petition to Distribute TCJA Savings~~Pennsylvania Activities

Act 129 (PPL and PPL Electric)

The Pennsylvania Public Utility Code requires electric distribution companies, including PPL Electric, ~~submitted~~to act as a ~~petition~~DSP, which provides electricity generation supply service to customers pursuant to a PUC-approved default service procurement plan. The DSP is able to recover the costs associated with its default service procurement plan.

In March 2020, PPL Electric filed a Petition for ~~approval~~Approval of a new default service program and procurement plan with the PUC ~~on October 4, 2019 to distribute the tax savings of $43 million associated with the TCJA~~ for the period ~~between January~~June 1, ~~2018 and June 30, 2018. As of September 30, 2019, these tax savings are classified as a noncurrent regulatory liability.~~2021 through May 31, 2025. This proceeding remains pending before the PUC. PPL Electric ~~has proposed that these amounts be distributed over~~cannot predict the ~~period~~outcome of ~~January 1, 2020 through December 31, 2020. The petition is contingent upon PUC approval.~~this proceeding.

Federal Matters

FERC Transmission Rate Filing

(PPL, LKE, LG&E and KU)

Table of Contents

horizontal market power concerns arising out of the 1998 ~~merger for certain transmission service between MISO and~~ LG&E and ~~KU. The affected transmission customers are a limited number of municipalities in Kentucky.~~KU merger and 2006 MISO withdrawal. The amounts at issue are generally waivers or credits granted to ~~such customers~~a limited number of Kentucky municipalities for either certain LG&E and KU or MISO transmission charges incurred ~~depending upon the direction of certain~~for transmission service ~~incurred by the municipalities.~~received. Due to the development of robust, accessible energy markets over time, LG&E and KU believe the mitigation commitments are no longer relevant or appropriate. OnIn March ~~21,~~ 2019, the FERC ~~issued an Order granting~~granted LG&E's and KU's request to remove the ~~on-going~~ongoing credits, conditioned upon the implementation by LG&E and KU of a transition mechanism for certain existing power supply arrangements, ~~which transition mechanism will be~~ subject to FERC review and approval. OnIn July ~~12,~~ 2019, LG&E and KU ~~submitted~~proposed their ~~proposed~~ transition mechanism to the ~~FERC. On~~FERC and in September ~~10,~~ 2019, the FERC ~~issued an order rejecting~~rejected the proposed transition ~~mechanism. On~~mechanism and issued a separate order providing clarifications of certain aspects of the March order. In October ~~10,~~ 2019, LG&E and KU filed ~~a request~~requests for rehearing and clarification on the two September ~~order.~~orders. In November 2019, the FERC granted LG&E and KU's and other parties' rehearing requests. Additionally, certain petitions for review of FERC's orders have been filed by multiple parties, including LG&E and KU, at the D.C. Circuit Court of Appeals. LG&E and KU cannot predict the outcome of ~~this proceeding.~~the proceedings. In February 2020, the D.C. Circuit Court of Appeals issued an order holding the various appeals in abeyance pending the FERC's rehearing process. LG&E and KU currently receive recovery of waivers and credits provided through other rate mechanisms.

(PPL and PPL Electric)

In April ~~2019,~~2020, PPL Electric filed its annual transmission formula rate update with the FERC, reflecting a revised revenue requirement ~~which includes the impact of the TCJA. The filing established the revenue requirement used to set rates~~ that ~~took~~will take effect in June ~~2019.~~

~~Transmission Customer Complaint(PPL, LKE, LG&E and KU)~~

In September 2018, a transmission customer filed a complaint with the FERC against LG&E and KU alleging LG&E and KU have violated and continue to violate their obligations under an existing rate schedule to credit this customer for certain transmission charges from MISO. On February 21, 2019, the FERC issued an Order concluding that the MISO transmission charges in question did qualify for credits under the rate schedule and required LG&E and KU to reimburse the customer for the eligible credits. The reimbursement was not significant and was completed by LG&E and KU in March 2019. LG&E and KU currently receive recovery for such credits through other rate mechanisms.

~~Table of Contents~~

~~TCJA Impact on FERC Rates~~ ~~(All Registrants)~~

In November 2018, the FERC issued a Policy Statement stating that the appropriate ratemaking treatment for changes in accumulated deferred income taxes (ADIT) as a result of the TCJA would be addressed in a Notice of Proposed Rulemaking. Also in November 2018, the FERC issued the Notice of Proposed Rulemaking, which proposed that public utility transmission providers include mechanisms in their formula rates to deduct excess ADIT from, or add deficient ADIT to, rate base and adjust their income tax allowances by amortized excess or deficient ADIT. The Notice of Proposed Rulemaking did not prescribe the mechanism companies should use to adjust their formula rates.

LG&E and KU are currently assessing the Notice of Proposed Rulemaking and are continuing to monitor guidance issued by the FERC. On February 5, 2019, in connection with a separate element of federal and Kentucky state tax reform effects, LG&E and KU filed a request with the FERC to amend their transmission formula rates to incorporate reductions to corporate income tax rates as a result of the TCJA and HB 487. The FERC approved this request effective June 1, 2019. LG&E and KU do not anticipate the impact of the TCJA and HB 487 related to their FERC-jurisdictional rates to be significant.

On February 28, 2019, PPL Electric filed with the FERC proposed revisions to its transmission formula rate template pursuant to Section 205 of the Federal Power Act and Section 35.13 of the Rules and Regulations of the FERC. Specifically, PPL Electric proposed to modify its formula rate to permit the return or recovery of excess or deficient ADIT resulting from the TCJA and permit PPL Electric to prospectively account for the income tax expense associated with the depreciation of the equity component of the AFUDC. On April 29, 2019, the FERC accepted the proposed revisions to the formula rate template, which were effective June 1, 2019, as well as the proposed adjustments to ADIT, effective January 1, 2018.2020.

Other

Purchase of Receivables Program (PPL and PPL Electric)

In accordance with a PUC-approved purchase of accounts receivable program, PPL Electric purchases certain accounts receivable from alternative electricity suppliers at a discount, which reflects a provision for ~~uncollectible accounts.~~credit losses. The alternative electricity suppliers have no continuing involvement or interest in the purchased accounts receivable. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. During the three ~~and nine~~ months ended ~~September 30,~~March 31, 2020 and 2019, PPL Electric purchased ~~$308~~$311 million and ~~$927~~$348 million ~~of accounts receivable from alternate suppliers. During the three and nine months ended September 30, 2018, PPL Electric purchased $334 million and $1 billion~~ of accounts receivable from alternate suppliers.

8. Financing Activities

Credit Arrangements and Short-term Debt

(All Registrants)

The Registrants maintain credit facilities to enhance liquidity, provide credit support and act as a backstop to commercial paper programs. For reporting purposes, on a consolidated basis, the credit facilities and commercial paper programs of PPL Electric, LKE, LG&E and KU also apply to PPL and the credit facilities and commercial paper programs of LG&E and KU also apply to LKE. The amounts listed in the borrowed column below are recorded as "Short-term debt" on the Balance ~~Sheets, except for amounts borrowed under LG&E's Term Loan Facility which were recorded as "Long-term debt due within one year" on the December 31, 2018 Balance Sheet.~~Sheets. The following credit facilities were in place at:

Table of Contents


	September 30, 2019									December 31, 2018				March 31, 2020									December 31, 2019
	Expiration Date	Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Expiration Date	Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity		Borrowed		Letters of Credit and Commercial Paper Issued
PPL
U.K.
WPD plc
Syndicated Credit Facility (a)	Jan. 2023	£	210	£	165	£	—	£	46	£	157	£	—	Jan. 2023	£	210	£	156	£	—	£	56	£	155	£	—
WPD (South West)
Syndicated Credit Facility(b)	July 2021	245		—		—		245		—		—		July 2021	245		—		—		245		40		—
WPD (East Midlands)
Syndicated Credit Facility ~~(b)~~	July 2021	300		—		—		300		38		—		July 2021	300		—		—		300		—		—
WPD (West Midlands)
Syndicated Credit Facility (c)	July 2021	300		51		—		249		—		—		July 2021	300		54		—		246		48		—
Uncommitted Credit Facilities ~~(d)~~		100		36		4		60		—		4			100		—		4		96		—		4
Total U.K. Credit Facilities ~~(e)~~(d)		£	1,155	£	252	£	4	£	900	£	195	£	4		£	1,155	£	210	£	4	£	943	£	243	£	4
U.S.
PPL Capital Funding(e)
Syndicated Credit Facility	Jan. 2024	$	1,450	$	—	$	981	$	469	$	—	$	669	Jan. 2024	$	1,450	$	575	$	180	$	695	$	—	$	450
Term Loan Credit Facility														Mar. 2021	200		200		—		—		—		—
Bilateral Credit Facility														Mar. 2021	50		50		—		—		—		—
Bilateral Credit Facility	Mar. 2020	100		—		15		85		—		15		Mar. 2021	50		34		15		1		—		15
Total PPL Capital Funding Credit Facilities		$	1,550	$	—	$	996	$	554	$	—	$	684		$	1,750	$	859	$	195	$	696	$	—	$	465

PPL Electric
Syndicated Credit Facility	Jan. 2024	$	650	$	—	$	1	$	649	$	—	$	1
Syndicated Credit Facility (f)														Jan. 2024	$	650	$	85	$	1	$	564	$	—	$	1

LG&E
Syndicated Credit Facility	Jan. 2024	$	500	$	—	$	99	$	401	$	—	$	279
Term Loan Credit Facility		—		—		—		—		200		—
Syndicated Credit Facility (g)														Jan. 2024	$	500	$	100	$	59	$	341	$	—	$	238
Total LG&E Credit Facilities		$	500	$	—	$	99	$	401	$	200	$	279		$	500	$	100	$	59	$	341	$	—	$	238

KU
Syndicated Credit Facility	Jan. 2024	$	400	$	—	$	2	$	398	$	—	$	235
Letter of Credit Facility (f)		—		—		—		—		—		198
Syndicated Credit Facility (g)														Jan. 2024	$	400	$	100	$	44	$	256	$	—	$	150
Total KU Credit Facilities		$	400	$	—	$	2	$	398	$	—	$	433		$	400	$	100	$	44	$	256	$	—	$	150

(a)

The amounts borrowed at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018~~2019 were USD-denominated borrowings of $200 million for both periods, which bore interest at ~~2.94%~~2.43% and ~~3.17%~~2.52%. The interest rates on the borrowings are equal to one-month USD LIBOR plus a spread. The unused capacity reflects the amounts borrowed in GBP of ~~£164~~£154 million as of the date borrowed.


(b)	The amount borrowed at December 31, ~~2018~~2019 was GBP-denominated borrowings which equated to ~~$48~~$51 million and bore interest at ~~1.12%~~1.09%.


(c)	The amount borrowed at ~~September 30,~~March 31, 2020 and December 31, 2019 ~~was~~were GBP-denominated borrowings which equated to $69 million and $62 million and bore interest at 1.11%. The interest rates on the borrowings are equal to one-month GBP LIBOR plus a margin.


(d)	~~The amount borrowed at September 30, 2019 was GBP-denominated borrowings which equated to $44 million and bore interest at 1.59%.~~


~~(e)~~	At ~~September 30, 2019,~~March 31, 2020, the unused capacity under the U.K. credit facilities was ~~$1.1~~$1.2 billion.


(e)	The interest rates on the borrowings are based on one-month LIBOR plus a spread, which resulted in a weighted-average rate of 1.97% at March 31, 2020.


(f)	~~KU's letter of credit facility~~The interest rate on the borrowing is equal to one-month LIBOR plus a spread, which was ~~terminated in September 2019 in connection with~~1.96% at March 31, 2020.


(g)	The interest rates on the ~~bond remarketings discussed below.~~borrowings are equal to one-month LIBOR plus a spread, which were 1.81% at March 31, 2020.

(PPL)

In March 2020, PPL Capital Funding entered into a $200 million term loan credit facility expiring in March 2021 and borrowed the full principal amount under the facility at an initial interest rate of 1.96%. The applicable interest rate on borrowings fluctuates periodically and is based on LIBOR plus a spread. The proceeds were used to repay short-term debt and for general corporate purposes.

Table of Contents

On April 1, 2020, PPL Capital Funding entered into a $100 million term loan credit facility expiring in March 2021 and borrowed the full principal amount under the facility at an initial interest rate of 1.73%. The applicable interest rate on borrowings fluctuates periodically and is based on LIBOR plus a spread. The proceeds will be used to repay short-term debt and for general corporate purposes.

PPL has guaranteed PPL Capital Funding's obligations under these credit agreements.

(All Registrants)

PPL, PPL Electric, LG&E and KU maintain commercial paper programs to provide an additional financing source to fund short-term liquidity ~~needs, as necessary.~~needs. Commercial paper issuances, included in "Short-term debt" on the Balance Sheets, are supported by the respective Registrant's credit facilities. The following commercial paper programs were in place at:

~~Table of Contents~~


	September 30, 2019							December 31, 2018			March 31, 2020							December 31, 2019
	Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances		Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances
PPL Capital Funding	2.52%	$	1,500	$	981	$	519	2.82%	$	669	1.91%	$	1,500	$	180	$	1,320	2.13%	$	450
PPL Electric		650		—		650			—			650		—		650			—
LG&E	2.29%	350		99		251		2.94%	279		1.71%	350		59		291		2.07%	238
KU	2.24%	350		2		348		2.94%	235		1.65%	350		44		306		2.02%	150
Total		$	2,850	$	1,082	$	1,768		$	1,183		$	2,850	$	283	$	2,567		$	838

(PPL Electric, LKE, LG&E, and KU)

See Note 1211 for discussion of intercompany borrowings.

Long-term Debt

(PPL)

~~In June 2019, WPD plc executed and drew £50~~On April 1, 2020, PPL Capital Funding entered into a $100 million ~~under a 5-year~~ term loan credit facility ~~due 2024~~expiring in March 2022 and borrowed the full principal amount under the facility at aan initial interest rate of ~~2.189%, to be reset quarterly as detailed in the terms of the agreement.~~1.72%. The ~~borrowing equated to $63 million at the time of drawdown, net of fees.~~applicable interest rate on borrowings fluctuates periodically and is based on LIBOR plus a spread. The proceeds ~~were used for general corporate purposes.~~

In September 2019, WPD (East Midlands) issued £250 million of 1.75% Senior Notes due 2031. WPD (East Midlands) received proceeds of £245 million, which equated to $301 million at the time of issuance, net of fees and a discount. The proceeds were used to repay short-term debt and for general corporate purposes.

~~(PPL, LKE and LG&E)~~

In April 2019, LG&E issued $400 million of 4.25% First Mortgage Bonds due 2049. LG&E received proceeds of $396 million, net of discounts and underwriting fees, which were used to repay commercial paper and LG&E's term loan.

In April 2019, the County of Jefferson, Kentucky remarketed $128 million of Pollution Control Revenue Bonds, 2001 Series A due 2033 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will ~~bear interest at 1.85% through their mandatory purchase date of April 1, 2021.~~

In June 2019, the Louisville/Jefferson County Metro Government of Kentucky remarketed $31 million of Environmental Facilities Revenue Refunding Bonds, 2007 Series A due 2033 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.65% through their mandatory purchase date of June 1, 2021.

In June 2019, the Louisville/Jefferson Country Metro Government of Kentucky remarketed $35 million of Environmental Facilities Revenue Refunding Bonds, 2007 Series B due 2033 previously issued on behalf of LG&E. The bonds were remarketed at a long-term rate and will bear interest at 1.65% through their mandatory purchase date of June 1, 2021.

In June 2019, LG&E issued a notice to bondholders of its intention to convert the $40 million Louisville/Jefferson County Metro Government of Kentucky Pollution Control Revenue Bonds, 2005 Series A to a weekly interest rate, as permitted under the loan documents. The conversion was completed on August 1, 2019. In connection with the conversion, LG&E purchased these bonds from the remarketing agent and held them until September 17, 2019, at which time LG&E remarketed the bonds at a long-term rate that will bear interest at 1.75% through their mandatory purchase date of July 1, 2026.

~~(PPL, LKE and KU)~~

In April 2019, KU reopened its 4.375% First Mortgage Bonds due 2045 and issued an additional $300 million of this series. KU received proceeds of $303 million, including premiums and underwriting fees, which were used to repay commercial paper and for other general corporate purposes.

In September 2019, the County of Carroll, Kentucky remarketed $50 million of Environmental Facilities Revenue Bonds, 2004 Series A due 2034 previously issued on behalf of KU. The bonds were remarketed at a long-term rate and will bear interest at 1.75% through their mandatory purchase date of September 1, 2026.

~~Table of Contents~~

In September 2019, the County of Carroll, Kentucky remarketed $96 million of Pollution Control Revenue Refunding Bonds, 2016 Series A due 2042 previously issued on behalf of KU. The bonds were remarketed at a long-term rate and will bear interest at 1.55% through their mandatory purchase date of September 1, 2026.

In September 2019, the County of Carroll, Kentucky remarketed $54 million of Environmental Facilities Revenue Refunding Bonds, 2006 Series B due 2034 previously issued on behalf of KU. The bonds were remarketed at a long-term rate and will bear interest at 1.20% through their mandatory purchase date of June 1, 2021.

In September 2019, the County of Carroll, Kentucky remarketed $78 million of Environmental Facilities Revenue Bonds, 2008 Series A due 2032 previously issued on behalf of KU. The bonds were remarketed at a long-term rate and will bear interest at 1.20% through their mandatory purchase date of June 1, 2021.

In September 2019, the County of Mercer, Kentucky remarketed $13 million of Solid Waste Disposal Facility Revenue Bonds, 2000 Series A due 2023 previously issued on behalf of KU. The bonds were remarketed at a long-term rate and will bear interest at 1.30% through the maturity date of May 1, 2023.

~~(PPL and PPL Electric)~~

~~In September 2019, PPL Electric issued $400 million of 3.00% First Mortgage Bonds due 2049. PPL Electric received proceeds of $390 million, net of a discount and underwriting fees, which were~~be used to repay short-term debt and for general corporate purposes.

On ~~October 31, 2019,~~April 1, 2020, PPL ~~Electric gave notice~~Capital Funding issued $1 billion of ~~its intent~~4.125% Senior Notes due 2030. PPL Capital Funding received proceeds of $993 million, net of a discount and underwriting fees, which will be used to ~~redeem all of the currently outstanding $100 million aggregate principal amount of its Senior Secured Bonds, 5.15% Series due 2020 on December 4, 2019.~~repay short-term debt and for general corporate purposes.

~~(PPL)~~PPL has guaranteed PPL Capital Funding's obligations under the credit agreement and notes.

Equity Securities

ATM Program

In February 2018, PPL entered into an equity distribution agreement, pursuant to which PPL may sell, from time to time, up to an aggregate of $1.0 billion of its common stock through an at-the-market offering ~~program;~~program, including a forward sales component. The compensation paid to the selling agents by PPL may be up to 2% of the gross offering proceeds of the shares. There were 0 issuances under the ATM program for the ~~nine~~three months ended ~~September 30, 2019.~~March 31, 2020.

Distributions

In ~~August 2019,~~February 2020, PPL declared a quarterly common stock dividend, payable ~~October~~April 1, ~~2019,~~2020, of ~~41.25~~41.50 cents per share (equivalent to ~~$1.65~~$1.66 per annum). Future dividends, declared at the discretion of the Board of Directors, will depend upon future earnings, cash flows, financial and legal requirements and other factors.

~~9. Leases~~

~~(All Registrants)~~

The Registrants determine whether contractual arrangements contain a lease by evaluating whether those arrangements either implicitly or explicitly identify an asset, whether the Registrants have the right to obtain substantially all of the economic benefits from use of the asset throughout the term of the arrangement, and whether the Registrants have the right to direct the use of the asset. Renewal options are included in the lease term if it is reasonably certain the Registrants will exercise those options. Periods for which the Registrants are reasonably certain not to exercise termination options are also included in the lease term. The Registrants have certain agreements with lease and non-lease components, such as office space leases, which are generally accounted for separately.

LKE, LG&E and KU have entered into various operating leases primarily for office space, vehicles and railcars. The leases generally have fixed payments with expiration dates ranging from 2019 to 2025, some of which have options to extend the leases from one year to ten years and some have options to terminate at LKE's, LG&E's and KU's discretion. For leases that

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~~existed as of December 31, 2018, payments associated with renewal options are not included in the measurement of the lease liability and right-of-use (ROU) asset.~~

PPL has also entered into various operating leases primarily for office space, land easements, telecom assets and warehouse space. These leases generally have fixed payments with expiration dates ranging from 2019 through 2028, except for the land agreements which extend through 2116.

~~PPL Electric also has operating leases which do not have a significant impact to its operations.~~

~~Short-term Leases~~

Short-term leases are leases with a term that is 12 months or less and do not include a purchase option or option to extend the initial term of the lease to greater than 12 months that the Registrants are reasonably certain to exercise. The Registrants have made an accounting policy election to not recognize the ROU asset and the lease liability arising from leases classified as short-term. Expenses related to short-term leases are included in the tables below.

~~Discount Rate~~

The discount rate for a lease is the rate implicit in the lease unless that rate cannot be readily determined. In that case, the Registrants are required to use their incremental borrowing rate, which is the rate the Registrants would have to pay to borrow, on a collateralized basis over a similar term, an amount equal to the lease payments in a similar economic environment.

The Registrants receive secured borrowing rates from financial institutions based on their applicable credit profiles. The Registrants use the secured rate which corresponds with the term of the applicable lease.

~~Practical Expedients~~

~~See Note 2 for information on the adoption of the new lease guidance as well as the practical expedients the Registrants have elected as part of the transition.~~

~~(PPL, LKE, LG&E and KU)~~

~~Lessee Transactions~~

~~The following table provides the components of lease cost for the Registrants' operating leases for the periods ended September 30, 2019.~~

Three Months
PPL LKE LG&E KU
Lease cost:
Operating lease cost $ 6
$ 5
$ 1
$ 3
Short-term lease cost 2
1
—
1
Total lease cost $ 8
$ 6
$ 1
$ 4

Nine Months
PPL LKE LG&E KU
Lease cost:
Operating lease cost $ 21
$ 17
$ 7
$ 9
Short-term lease cost 5
2
1
1
Total lease cost $ 26
$ 19
$ 8
$ 10

~~The following table provides other key information related to the Registrants' operating leases at September 30, 2019.~~

PPL LKE LG&E KU
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases $ 21
$ 17
$ 8
$ 9
Right-of-use asset obtained in exchange for new operating lease liabilities 37
8
3
5

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The following table provides the total future minimum rental payments for operating leases, as well as a reconciliation of these undiscounted cash flows to the lease liabilities recognized on the Balance Sheets as of September 30, 2019.

PPL LKE LG&E KU
2019 (a) $ 8
$ 5
$ 2
$ 3
2020 27
16
6
10
2021 21
12
5
7
2022 16
8
3
5
2023 14
7
3
3
2024 12
6
3
3
Thereafter 25
7
3
3
Total $ 123
$ 61
$ 25
$ 34

Weighted-average discount rate
3.47 % 3.97 % 3.9 % 4.01 %
Weighted-average remaining lease term (in years)
8
5
5
5
Current lease liabilities (b) $ 25
$ 16
$ 6
$ 9
Non-current lease liabilities (b) 80
39
16
22
Right-of-use assets (c) 97
47
19
27


~~(a)~~	~~Represents future minimum lease payments for the remainder of 2019.~~


~~(b)~~	Current lease liabilities are included in "Other Current Liabilities" on the Balance Sheets. Non-current lease liabilities are included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets. The difference between the total future minimum lease payments and the recorded lease liabilities is due to the impact of discounting.


~~(c)~~	~~Right-of-use assets are included in "Other noncurrent assets" on the Balance Sheets.~~

~~At December 31, 2018, the total future minimum rental payments for all operating leases were estimated to be:~~

PPL LKE LG&E KU
2019 $ 26
$ 20
$ 10
$ 10
2020 21
15
6
9
2021 15
11
4
7
2022 13
7
3
4
2023 8
6
3
3
Thereafter 33
11
4
6
Total $ 116
$ 70
$ 30
$ 39

~~Lessor Transactions~~

Third parties lease land from LKE, LG&E and KU at certain generation plants to produce refined coal used to generate electricity. The leases are operating leases and expire in 2021. Payments are allocated among lease and non-lease components as stated in the agreements. Lease payments are fixed or are determined based on the amount of refined coal used in electricity generation at the facility. Payments received are primarily recorded as a regulatory liability and are amortized in accordance with regulatory approvals.

~~WPD leases property and telecom assets to third parties, which generally expire through 2029. These leases are operating leases. Generally, lease payments are fixed and include only a lease component.~~

~~At September 30, 2019, PPL, LKE, LG&E and KU expect to receive the following fixed lease payments over the remaining term of their operating lease agreements:~~

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PPL LKE LG&E KU
2019 (a) $ 3
$ 2
$ —
$ 2
2020 13
7
—
7
2021 10
5
1
4
2022 4
—
—
—
2023 4
1
—
—
2024 4
—
—
—
Thereafter 12
—
—
—
Total $ 50
$ 15
$ 1
$ 13

Lease income recognized for the three months ended September 30, 2019 $ 6
$ 4
$ 2
$ 2
Lease income recognized for the nine months ended September 30, 2019 $ 16
$ 10
$ 4
$ 6


~~(a)~~	~~Represents future minimum lease payments for the remainder of 2019.~~

~~10.~~9. Defined Benefits

(PPL, LKE and LG&E)

Certain net periodic defined benefit costs are applied to accounts that are further distributed among capital, expense, regulatory assets and regulatory liabilities, including certain costs allocated to applicable subsidiaries for plans sponsored by PPL Services and LKE. Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries, LKE, and LG&E for the periods ended ~~September 30:~~March 31:


	Pension Benefits																								Pension Benefits
	Three Months												Nine Months												Three Months
	U.S.						U.K.						U.S.						U.K.						U.S.						U.K.
	2019			2018			2019			2018			2019			2018			2019			2018			2020			2019			2020			2019
PPL
Service cost	$	13		$	15		$	17		$	21		$	38		$	46		$	51		$	63		$	13		$	13		$	23		$	17
Interest cost	41			39			45			46			123			117			140			140			38			41			36			47
Expected return on plan assets	(62		)	(62		)	(144		)	(145		)	(184		)	(186		)	(442		)	(445		)	(60		)	(61		)	(158		)	(148		)
Amortization of:
Prior service cost	2			2			1			—			6			7			1			—			2			2			—			—
Actuarial loss	15			22			22			37			42			63			69			114			20			13			54			24
Net periodic defined benefit costs (credits) before settlements	9			16			(59		)	(41		)	25			47			(181		)	(128		)	13			8			(45		)	(60		)
Settlements	—			—			—			—			1			—			—			—			—			1			—			—
Net periodic defined benefit costs (credits)	$	9		$	16		$	(59	)	$	(41	)	$	26		$	47		$	(181	)	$	(128	)	$	13		$	9		$	(45	)	$	(60	)


	Pension Benefits												Pension Benefits
	Three Months						Nine Months						Three Months
	2019			2018			2019			2018			2020			2019
LKE
Service cost	$	5		$	6		$	16		$	18		$	5		$	6
Interest cost	16			16			49			48			16			16
Expected return on plan assets	(25		)	(25		)	(76		)	(76		)	(24		)	(25		)
Amortization of:
Prior service cost	2			3			6			7			2			2
Actuarial loss (a)	7			8			17			26			9			4
Net periodic defined benefit costs ~~(b)~~	$	5		$	8		$	12		$	23		$	8		$	3

(a)

As a result of treatment approved by the KPSC, the difference between actuarial loss calculated in accordance with LKE's accounting policy and actuarial loss calculated using a 15-year amortization period was ~~$2 million and~~ $3 million for the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 and ~~$2 million and $8 million~~not significant for the three ~~and nine~~ months ended ~~September 30, 2018.~~March 31, 2019. This difference is recorded as a regulatory asset.



	Pension Benefits
	Three Months
	2019 (a)
LG&E
Interest cost	$	3
Expected return on plan assets	(6		)
Amortization of:
Prior service cost	1
Actuarial loss	2
Net periodic defined benefit costs	$	—


(a)	The pension plans sponsored by LKE and LG&E were merged effective January 1, 2020 into the LG&E and KU Pension Plan, sponsored by LKE

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~~(b)~~

Due to the amount of lump sum payment distributions from the LG&E qualified pension plan, a settlement charge of $5 million for the three and nine months ended September 30, 2019 and $1 million and $5 million for the three and nine months ended September 30, 2018 was incurred. In accordance with existing regulatory accounting treatment, LG&E has maintained the settlement charge in regulatory assets. The amount is being amortized in accordance with existing regulatory practice.

Pension Benefits
Three Months Nine Months
2019 2018 2019 2018
LG&E
Service cost $ —
$ —
$ 1
$ 1
Interest cost 2
3
8
9
Expected return on plan assets (5 ) (6 ) (16 ) (17 )
Amortization of:
Prior service cost 1
1
4
4
Actuarial loss (a) 4
2
7
5
Net periodic defined benefit costs (b) $ 2
$ —
$ 4
$ 2

~~(a)~~

As a result of treatment approved by the KPSC, the difference between actuarial loss calculated in accordance with LG&E's accounting policy and actuarial loss calculated using a 15-year amortization period was $1 million and $2 million for the three and nine months ended September 30, 2019 and $1 million for the nine months ended September 30, 2018. This difference is recorded as a regulatory asset.

~~(b)~~


	Other Postretirement Benefits												Other Postretirement Benefits
	Three Months						Nine Months						Three Months
	2019			2018			2019			2018			2020			2019
PPL
Service cost	$	2		$	1		$	4		$	5		$	2		$	1
Interest cost	5			5			16			15			5			6
Expected return on plan assets	(5		)	(4		)	(14		)	(17		)	(5		)	(5		)
Amortization of actuarial loss	1			—			1			—
Net periodic defined benefit costs	$	3		$	2		$	7		$	3		$	2		$	2

LKE
Service cost	$	1		$	1		$	3		$	3		$	1		$	1
Interest cost	2			2			6			6			2			2
Expected return on plan assets	(2		)	(2		)	(6		)	(6		)	(2		)	(2		)
Amortization of:
Prior service cost	—			—			1			1
Actuarial gain	—			—			(1		)	(1		)
Net periodic defined benefit costs	$	1		$	1		$	3		$	3		$	1		$	1

(PPL Electric, LG&E and KU)

~~In addition to the specific plan it sponsors, LG&E is allocated costs of defined benefit plans sponsored by LKE. PPL Electric and KU do not directly sponsor any defined benefit plans.~~ PPL Electric is allocated costs of defined benefit plans sponsored by PPL Services and LG&E and KU isare allocated costs of defined benefit plans sponsored by LKE. LG&E and KU are also allocated costs of defined benefit plans from LKS for defined benefit plans sponsored by LKE. See Note 1211 for additional information on costs allocated to LG&E and KU from LKS. These allocations are based on participation in those plans, which management believes are reasonable. For the periods ended ~~September 30,~~March 31, PPL Services allocated the following net periodic defined benefit costs to PPL Electric, and LKE allocated the following net periodic defined benefit costs to LG&E and KU:

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	Three Months				Nine Months				Three Months
	2019		2018		2019		2018		2020		2019
PPL Electric	$	3	$	5	$	8	$	12	$	3	$	3
LG&E(a)	1		1		3		5		3		1
KU	—		1		—		3		1		—


(a)	Allocations to LG&E increased in 2020 primarily due to the merger of plans sponsored by LKE and LG&E effective January 1, 2020 into the LG&E and KU Pension Plan.

(All Registrants)

The non-service cost components of net periodic defined benefit costs (credits) (interest cost, expected return on plan assets, amortization of prior service cost and amortization of actuarial gain and loss) are presented in "Other Income (Expense) - net" on the Statements of Income. See Note 1312 for additional information.

~~11.~~10. Commitments and Contingencies

Legal Matters

(All Registrants)

PPL and its subsidiaries are involved in legal proceedings, claims and litigation in the ordinary course of business. PPL and its subsidiaries cannot predict the outcome of such matters, or whether such matters may result in material liabilities, unless otherwise noted.

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Talen Litigation (PPL)

Background

In September 2013, one of PPL's former subsidiaries, PPL Montana entered into an agreement to sell its hydroelectric generating facilities. In June 2014, PPL and PPL Energy Supply, the parent company of PPL Montana, entered into various definitive agreements with affiliates of Riverstone to spin off PPL Energy Supply and ultimately combine it with Riverstone's competitive power generation businesses to form a stand-alone company named Talen Energy. In November 2014, after executing the spinoff agreements but prior to the closing of the spinoff transaction, PPL Montana closed the sale of its hydroelectric generating facilities. Subsequently, on June 1, 2015, the spinoff of PPL Energy Supply was completed. Following the spinoff transaction, PPL had no continuing ownership interest in or control of PPL Energy Supply. In connection with the spinoff transaction, PPL Montana became Talen Montana, LLC (Talen Montana), a subsidiary of Talen Energy. Talen Energy Marketing also became a subsidiary of Talen Energy as a result of the June 2015 spinoff of PPL Energy Supply. Talen Energy has owned and operated both Talen Montana and Talen Energy Marketing since the spinoff. At the time of the spinoff, affiliates of Riverstone acquired a 35% ownership interest in Talen Energy. Riverstone subsequently acquired the remaining interests in Talen Energy in a take private transaction in December 2016.

Talen Montana, LLC v. PPL Corporation et al.

On October 29, 2018, Talen Montana filed a complaint against PPL and certain of its affiliates and current and former officers and directors in the First Judicial District of the State of Montana, Lewis & Clark County (Talen Direct Action). Talen Montana alleges that in November 2014, PPL and certain officers and directors improperly distributed to PPL's subsidiaries $733 million of the proceeds from the sale of Talen Montana's (then PPL Montana's) hydroelectric generating facilities, rendering PPL Montana insolvent. The complaint includes claims for, among other things, breach of fiduciary duty; aiding and abetting breach of fiduciary duty; breach of an LLC agreement; breach of the implied duty of good faith and fair dealing; tortious interference; negligent misrepresentation; and constructive fraud. Talen Montana is seeking unspecified damages, including punitive damages, and other relief. In December 2018, PPL moved to dismiss the Talen Direct Action for lack of jurisdiction and, in the alternative, to dismiss because Delaware is the appropriate forum to decide this case. In January 2019, Talen Montana dismissed without prejudice all current and former PPL Corporation directors from the case. The parties engaged in limited jurisdictional discovery, and the Court heard oral argument regarding the PPL parties' motion to dismiss on August 22, 2019. ~~We are awaiting~~On December 4, 2019, the ~~Court's decision regarding the~~Court granted PPL's motion to ~~dismiss.~~

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dismiss and on December 26, 2019, a judgment dismissing all claims against all defendants with prejudice was signed by the Court. No appeal was filed and this matter is now concluded.

Talen Montana Retirement Plan and Talen Energy Marketing, LLC, Individually and on Behalf of All Others Similarly Situated v. PPL Corporation et al.

Also, on October 29, 2018, Talen Montana Retirement Plan and Talen Energy Marketing filed a putative class action complaint on behalf of current and contingent creditors of Talen Montana who allegedly suffered harm or allegedly will suffer reasonably foreseeable harm as a result of the November 2014 distribution. The action was filed in the Sixteenth Judicial District of the State of Montana, Rosebud County, against PPL and certain of its affiliates and current and former officers and directors (Talen Putative Class Action). The plaintiffs assert claims for, among other things, fraudulent transfer, both actual and constructive; recovery against subsequent transferees; civil conspiracy; aiding and abetting tortious conduct; and unjust enrichment. They are seeking avoidance of the purportedly fraudulent transfer, unspecified damages, including punitive damages, the imposition of a constructive trust, and other relief. In December 2018, PPL removed the Talen Putative Class Action from the Sixteenth Judicial District of the State of Montana to the United States District Court for the District of Montana, Billings Division (MT Federal Court). In January 2019, the plaintiffs moved to remand the Talen Putative Class Action back to state court, and dismissed without prejudice all current and former PPL Corporation directors from the case. In September 2019, the MT Federal Court granted plaintiffs' motion to remand the case back to state court, and the PPL defendants promptly petitioned the Ninth Circuit Court of Appeals to grant an appeal of the remand decision. ~~The petition for appeal is under consideration by~~On November 21, 2019, the Ninth Circuit Court of ~~Appeals.~~Appeals denied that request and on December 30, 2019, Talen Montana Retirement Plan filed a Second Amended Complaint in the Sixteenth Judicial District of the State of Montana, Rosebud County, which removed Talen Energy Marketing, LLC as a plaintiff. On January 31, 2020, PPL defendants filed a motion to dismiss the Second Amended Complaint. The Court has scheduled a hearing date of June 24, 2020 to hear oral argument regarding the motion to dismiss.

PPL Corporation et al. vs. Riverstone Holdings LLC, Talen Energy Corporation et al.

On November 30, 2018, PPL, certain PPL affiliates, and certain current and former officers and directors (PPL plaintiffs) filed a complaint in the Court of Chancery of the State of Delaware seeking various forms of relief against Riverstone, Talen Energy

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and certain of their affiliates (Delaware Action). In the complaint, the PPL plaintiffs ask the Delaware Court of Chancery for declaratory and injunctive relief. This includes a declaratory judgment that, under the separation agreement governing the spinoff of PPL Energy Supply, all related claims that arise must be heard in Delaware; that the statute of limitations in Delaware and the spinoff agreement bar these claims at this point; that PPL is not liable for the claims in either the Talen Direct Action or the Talen Putative Class Action as PPL Montana was solvent at all relevant times; and that the separation agreement requires that Talen Energy indemnify PPL for all losses arising from the debts of Talen Montana, among other things. PPL's complaint also seeks damages against Riverstone for interfering with the separation agreement and against Riverstone affiliates for breach of the implied covenant of good faith and fair dealing. The complaint was subsequently amended on January 11, 2019 and March 20, 2019, including to add claims related to indemnification with respect to the Talen Direct Action and the Talen Putative Class Action (together, the Montana Actions), request a declaration that the Montana Actions are time-barred under the spinoff agreements, and allege additional facts to support the tortious interference claim. In April 2019, the defendants filed motions to dismiss the amended complaint. In July 2019, the Court heard oral arguments from the parties regarding the motions to dismiss. On October 23, 2019, the Delaware Court of Chancery returned its opinion on the defendants’ motions to dismiss sustaining all of the PPL plaintiffs' claims except for the claim for breach of implied covenant of good faith and fair dealing. Discovery is underway; however, on January 30, 2020, Talen Energy filed a new motion to dismiss five of the remaining eight claims in the amended complaint. Oral argument on the motion to dismiss is scheduled for May 28, 2020. A tentative trial date has been scheduled for June 2021.

With respect to each of the Talen-related matters described above, PPL believes that the 2014 distribution of proceeds was made in compliance with all applicable laws and that PPL Montana was solvent at all relevant times. Additionally, the agreements entered into in connection with the spinoff, which PPL and affiliates of Talen Energy and Riverstone negotiated and executed prior to the 2014 distribution, directly address the treatment of the proceeds from the sale of PPL Montana's hydroelectric generating facilities; in those agreements, Talen Energy and Riverstone definitively agreed that PPL was entitled to retain the proceeds.

PPL believes that it has meritorious defenses to the claims made in the ~~Montana Actions~~Talen Putative Class Action and intends to continue to vigorously defend against ~~these actions.~~this action. The ~~Montana Actions~~Talen Putative Class Action and the Delaware Action are ~~all~~both in ~~the~~ early stages of litigation; at this time, PPL cannot predict the outcome of these matters or estimate the range of possible losses, if any, that PPL might incur as a result of the claims, although they could be material.

(PPL, LKE and LG&E)

Cane Run Environmental Claims~~(PPL, LKE and LG&E)~~

In December 2013, 6 residents, on behalf of themselves and others similarly situated, filed a class action complaint against LG&E and PPL in the U.S. District Court for the Western District of Kentucky (U.S. District Court) alleging violations of the Clean Air Act, RCRA, and common law claims of nuisance, trespass and negligence. These plaintiffs seek injunctive relief and civil penalties, plus costs and attorney fees, for the alleged statutory violations. Under the common law claims, these plaintiffs seek monetary compensation and punitive damages for property damage and diminished property values for a class consisting of residents within 4 miles of the Cane Run plant, which retired 3 coal-fired units in 2015. In their individual capacities, these plaintiffs sought compensation for alleged adverse health effects. In July 2014, the ~~court~~ U.S. District Court

dismissed the RCRA claims and

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all but 1 Clean Air Act claim, but declined to dismiss the common law tort claims. In ~~November 2016, the plaintiffs filed an amended complaint removing the personal injury claims and removing certain previously named plaintiffs. In~~ February 2017, the U.S. District Court ~~issued an Order dismissing~~dismissed PPL as a defendant and ~~dismissing~~dismissed the final federal claim against LG~~&E. In~~&E, and in April 2017, ~~the U.S. District Court~~ issued an Order declining to exercise supplemental jurisdiction on the state law claims ~~and dismissed~~dismissing the case in its entirety. In June 2017, the plaintiffs filed a class action complaint in Jefferson County, Kentucky Circuit Court, against LG&E alleging state law nuisance, negligence and trespass tort claims. The plaintiffs seek compensatory and punitive damages for alleged property damage due to purported plant emissions on behalf of a class of residents within 1 to 3 miles of the plant. ~~Proceedings are currently underway regarding potential~~On January 8, 2020, the Jefferson Circuit Court issued an order denying the plaintiffs’ request for class ~~certification, for which~~certification. On January 14, 2020, the plaintiffs filed a ~~decision may be rendered~~notice of appeal in ~~2019.~~the Kentucky Court of Appeals. PPL, LKE and LG&E cannot predict the outcome of this matter and an estimate or range of possible losses cannot be determined.

~~E.W. Brown Environmental Claims~~(PPL, LKE and KU)

E.W. Brown Environmental Claims

In July 2017, the Kentucky Waterways Alliance and the Sierra Club filed a citizen suit complaint against KU in the U.S. District Court for the Eastern District of Kentucky (U.S. District Court) alleging discharges at the E.W. Brown plant in violation of the Clean Water Act and the ~~plant’s~~plant's water discharge permit and alleging contamination that may present an imminent and substantial endangerment in violation of the RCRA. The ~~plaintiffs’~~plaintiffs' suit relates to prior notices of intent to file a citizen suit submitted in October and November 2015 and October 2016. These plaintiffs sought injunctive relief ordering KU to take all actions necessary to comply with the Clean Water Act and RCRA, including ceasing the discharges in question, abating effects associated with prior discharges and eliminating the alleged imminent and substantial endangerment. These plaintiffs also

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sought assessment of civil penalties and an award of litigation costs and attorney fees. In December 2017, the U.S. District Court issued an Order dismissing the Clean Water Act and RCRA complaints against KU in their entirety. In January 2018, the plaintiffs appealed the dismissal Order to the U.S. Court of Appeals for the Sixth Circuit. In September 2018, the U.S. Court of Appeals for the Sixth Circuit issued its ruling affirming the lower court's decision to dismiss the Clean Water Act claims but reversing its dismissal of the RCRA claims against KU and remanding the latter to the U.S. District Court. In October 2018, KU filed a petition for rehearing to the U.S. Court of Appeals for the Sixth Circuit regarding the RCRA claims. In November 2018, the U.S. Court of Appeals for the Sixth Circuit denied KU's petition for rehearing regarding the RCRA claims. OnIn January 8, 2019, KU filed an answer to plaintiffs’ complaint in the U.S. District Court. A trial has been scheduled to begin ~~on October 5, 2020.~~in February 2021. PPL, LKE and KU cannot predict the outcome of these matters and an estimate or range of possible losses cannot be determined.

KU is undertaking extensive remedial measures at the E.W. Brown plant including closure of the former ash pond, implementation of a groundwater remedial action plan and performance of a corrective action plan including aquatic study of adjacent surface waters and risk assessment. The aquatic study and risk assessment ~~was~~are being undertaken pursuant to a 2017 agreed Order with the Kentucky Energy and Environment Cabinet (KEEC). KU conducted sampling of Herrington Lake in 2017 and 2018. In June 2019, KU submitted to the KEEC the required aquatic study and risk assessment, conducted by an independent third-party consultant, ~~to the KEEC in June 2019~~ finding that discharges from the E.W. Brown plant have not had any significant impact on Herrington Lake and that the water in the lake is safe for recreational use and meets safe drinking water standards. However, until the KEEC assesses the study and issues any regulatory determinations, PPL, LKE and KU are unable to determine whether additional remedial measures will be required at the E.W. Brown plant.

Air

Sulfuric Acid Mist Emissions (PPL, LKE and LG&E)

In June 2016, the EPA issued a notice of violation under the Clean Air Act alleging that LG&E violated applicable rules relating to sulfuric acid mist emissions at its Mill Creek plant. The notice alleges failure to install proper controls, failure to operate the facility consistent with good air pollution control practice, and causing emissions exceeding applicable requirements or constituting a nuisance or endangerment. LG&E believes it has complied with applicable regulations during the relevant time period. Discussions between the EPA and LG&E are ongoing. The parties have entered into a tolling agreement with respect to this matter through July 31, 2020. The parties are conducting negotiations regarding potential settlement of the matter. PPL, LKE and LG&E are unable to predict the outcome of this matter or the potential impact on operations of the Mill Creek plant, including increased capital or operating costs, and potential civil penalties or remedial measures, if any.

Water/Waste

(PPL, LKE, LG&E and KU)

ELGs

In 2015, the EPA finalized ELGs for wastewater discharge permits for new and existing steam electricity generating facilities. These guidelines require deployment of additional control technologies providing physical, chemical and biological treatment and mandate operational changes including "no discharge" requirements for certain wastewaters. The implementation date for individual generating stations was to be determined by the states on a case-by-case basis according to criteria provided by the EPA. Legal challenges to the final rule were consolidated before the U.S. Court of Appeals for the Fifth Circuit. In April 2017, the EPA announced that it would grant petitions for reconsideration of the rule. In September 2017, the EPA issued a rule to postpone the compliance date for certain requirements. On November 25, 2019, the EPA issued proposed revisions to its best available technology standards for certain wastewaters. The EPA expects to complete its reconsideration of best available technology standards by the fall of 2020. Upon completion of the ongoing regulatory proceedings, the rule will be implemented by the states in the course of their normal permitting activities. LG&E and KU are developing compliance strategies and schedules. PPL, LKE, LG&E and KU are unable to predict the outcome of the EPA's pending reconsideration of the rule or fully estimate compliance costs or timing. Additionally, certain aspects of these compliance plans and estimates relate to developments in state water quality standards, which are separate from the ELG rule or its implementation. Costs to comply with ELGs or other discharge limits are expected to be significant. Certain costs are included in the Registrants' capital plans and are subject to rate recovery. See Note 7 for additional information regarding LG&E’s and KU’s applications for ECR rate treatment of construction costs relating to regulations addressing ELGs.

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CCRs

In 2015, the EPA issued a final rule governing management of CCRs which include fly ash, bottom ash and sulfur dioxide scrubber wastes. The CCR Rule imposes extensive new requirements for certain CCR impoundments and landfills, including public notifications, location restrictions, design and operating standards, groundwater monitoring and corrective action requirements, and closure and post-closure care requirements, and specifies restrictions relating to the beneficial use of CCRs. Legal challenges to the final rule are pending before the D.C. Circuit Court of Appeals. In July 2018, the EPA issued a final rule extending the deadline for closure of certain impoundments and adopting other substantive changes. In August 2018, the D.C. Circuit Court of Appeals vacated and remanded portions of the CCR Rule. In December 2019, the EPA addressed the deficiencies identified by the court and proposed amendments to change the closure deadline to August 31, 2020, but allow certain extensions. EPA has announced that additional amendments to the rule are planned. PPL, LKE, LG&E and KU are unable to predict the outcome of the ongoing litigation and rulemaking or potential impacts on current LG&E and KU compliance plans. The Registrants are currently finalizing closure plans and schedules.

In January 2017, Kentucky issued a new state rule relating to CCR management, effective May 2017, aimed at reflecting the requirements of the federal CCR rule. As a result of a subsequent legal challenge, in January 2018, the Franklin County, Kentucky Circuit Court issued an opinion invalidating certain procedural elements of the rule. LG&E and KU presently operate their facilities under continuing permits authorized under the former program and do not currently anticipate material impacts as a result of the judicial ruling. The Kentucky Energy and Environmental Cabinet has announced it intends to propose new state rules aimed at addressing procedural deficiencies identified by the court and providing the regulatory framework necessary for operation of the state program in lieu of the federal CCR Rule. Associated costs are expected to be subject to rate recovery.

LG&E and KU received KPSC approval for a compliance plan providing for the closure of impoundments at the Mill Creek, Trimble County, E.W. Brown, and Ghent stations, and construction of process water management facilities at those plants. In addition to the foregoing measures required for compliance with the federal CCR rule, KU also received KPSC approval for its plans to close impoundments at the retired Green River, Pineville and Tyrone plants to comply with applicable state law. Since 2017, LG&E and KU have commenced closure of many of the subject impoundments and have completed closure of some of their smaller impoundments. LG&E and KU expect to commence closure of the remaining impoundments no later than August 2020. LG&E and KU generally expect to complete impoundment closures within five years of commencement, although a longer period may be required to complete closure of some facilities. Associated costs are expected to be subject to rate recovery.

In connection with the final CCR rule, LG&E and KU recorded adjustments to existing AROs beginning in 2015 and continue to record adjustments as required. See Note 15 for additional information. Further changes to AROs, current capital plans or operating costs may be required as estimates are refined based on closure developments, groundwater monitoring results, and regulatory or legal proceedings. Costs relating to this rule are subject to rate recovery.

(All Registrants)

Superfund and Other Remediation

PPL Electric, LG&E and KU are potentially responsible for investigating and remediating contamination under the federal Superfund program and similar state programs. Actions are under way at certain sites including former coal gas manufacturing plants in Pennsylvania and Kentucky previously owned or operated by, or currently owned by predecessors or affiliates of, PPL Electric, LG&E and KU. PPL Electric is potentially responsible for a share of clean-up costs at certain sites including the Columbia Gas Plant site and the Brodhead site. Clean-up actions have been or are being undertaken at all of these sites, the costs of which have not been and are not expected to be significant to PPL Electric.

As of March 31, 2020 and December 31, 2019, PPL Electric had a recorded liability of $10 million representing its best estimate of the probable loss incurred to remediate the sites identified above. Depending on the outcome of investigations at identified sites where investigations have not begun or been completed, or developments at sites for which information is incomplete, additional costs of remediation could be incurred. PPL Electric, LG&E and KU lack sufficient information about such additional sites to estimate any potential liability or range of reasonably possible losses, if any, related to these sites. Such costs, however, are not expected to be significant.

The EPA is evaluating the risks associated with polycyclic aromatic hydrocarbons and naphthalene, chemical by-products of coal gas manufacturing. As a result, individual states may establish stricter standards for water quality and soil cleanup, that

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could require several PPL subsidiaries to take more extensive assessment and remedial actions at former coal gas manufacturing plants. PPL, PPL Electric, LKE, LG&E and KU cannot estimate a range of possible losses, if any, related to these matters.

Regulatory Issues (All Registrants)

See Note 7 for information on regulatory matters related to utility rate regulation.

Electricity - Reliability Standards

The NERC is responsible for establishing and enforcing mandatory reliability standards (Reliability Standards) regarding the bulk electric system in North America. The FERC oversees this process and independently enforces the Reliability Standards.

The Reliability Standards have the force and effect of law and apply to certain users of the bulk electric system, including electric utility companies, generators and marketers. Under the Federal Power Act, the FERC may assess civil penalties for certain violations.

PPL Electric, LG&E and KU monitor their compliance with the Reliability Standards and self-report or self-log potential violations of applicable reliability requirements whenever identified, and submit accompanying mitigation plans, as required. The resolution of a small number of potential violations is pending. Penalties incurred to date have not been significant. Any

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Regional Reliability Entity (including RFC or SERC) determination concerning the resolution of violations of the Reliability Standards remains subject to the approval of the NERC and the FERC.

In the course of implementing their programs to ensure compliance with the Reliability Standards by those PPL affiliates subject to the standards, certain other instances of potential non-compliance may be identified from time to time. The Registrants cannot predict the outcome of these matters, and an estimate or range of possible losses cannot be determined.

~~Environmental Matters~~

~~(All Registrants)~~

Due to the environmental issues discussed below or other environmental matters, it may be necessary for the Registrants to modify, curtail, replace or cease operation of certain facilities or performance of certain operations to comply with statutes, regulations and other requirements of regulatory bodies or courts. In addition, legal challenges to new environmental permits or rules add to the uncertainty of estimating the future cost of these permits and rules.

WPD's distribution businesses are subject to certain statutory and regulatory environmental requirements. It may be necessary for WPD to incur significant compliance costs, which costs may be recoverable through rates subject to the approval of Ofgem. PPL believes that WPD has taken and continues to take measures to comply with all applicable environmental laws and regulations.

LG&E and KU are entitled to recover, through the ECR mechanism, certain costs of complying with the Clean Air Act, as amended, and those federal, state or local environmental requirements applicable to coal combustion wastes and by-products from facilities that generate electricity from coal combustion in accordance with approved compliance plans. Costs not covered by the ECR mechanism for LG&E and KU and all such costs for PPL Electric are subject to rate recovery before the companies' respective state regulatory authorities, or the FERC, if applicable. Because neither WPD nor PPL Electric owns any generating plants, their exposure to related environmental compliance costs is reduced. PPL, PPL Electric, LKE, LG&E and KU can provide no assurances as to the ultimate outcome of future environmental or rate proceedings before regulatory authorities.

~~Air~~

~~(PPL, LKE, LG&E and KU)~~

~~NAAQS~~

The Clean Air Act, which regulates air pollutants from mobile and stationary sources in the United States, has a significant impact on the operation of fossil fuel generation plants. Among other things, the Clean Air Act requires the EPA periodically to review and establish concentration levels in the ambient air for six pollutants to protect public health and welfare. The six pollutants are carbon monoxide, lead, nitrogen dioxide, ozone (contributed to by nitrogen oxide emissions), particulate matter and sulfur dioxide. The established concentration levels for these six pollutants are known as NAAQS. Under the Clean Air Act, the EPA is required to reassess the NAAQS on a five-year schedule.

Federal environmental regulations of these six pollutants require states to adopt implementation plans, known as state implementation plans, which detail how the state will attain the standards that are mandated by the relevant law or regulation. Each state identifies the areas within its boundaries that meet the NAAQS (attainment areas) and those that do not (non-attainment areas), and must develop a state implementation plan both to bring non-attainment areas into compliance with the NAAQS and to maintain good air quality in attainment areas. In addition, for attainment of ozone and fine particulates standards, states in the eastern portion of the country, including Kentucky, are subject to a regional program developed by the EPA known as the Cross-State Air Pollution Rule. The NAAQS, future revisions to the NAAQS and state implementation plans, or future revisions to regional programs, may require installation of additional pollution controls, the costs of which PPL, LKE, LG&E and KU believe are subject to cost recovery.

~~Although PPL, LKE, LG&E and KU do not anticipate significant costs to comply with these programs, changes in market or operating conditions could result in different costs than anticipated.~~

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~~Ozone~~

The EPA issued the current ozone standard in October 2015. The states and the EPA are required to determine (based on ambient air monitoring data) those areas that meet the standard and those that are in nonattainment. In April 2018, the EPA designated Jefferson County, Kentucky (Louisville) as being in nonattainment with the ozone standard. Although implementation of the 2015 ozone standard could potentially require the addition of SCRs at LG&E's Mill Creek station, PPL, LKE and LG&E are unable to determine what, if any, compliance measures may ultimately be required until the Louisville Metro Air Pollution District prepares a state implementation plan.

States are also obligated to address interstate transport issues associated with ozone standards through the establishment of "good neighbor" state implementation plans for those states that are found to contribute significantly to another state's non-attainment. As a result of a partial consent decree addressing claims regarding federal implementation, the EPA and several states, including Kentucky, have evaluated the need for further nitrogen oxide reductions from fossil-fueled plants to address interstate impacts. In July 2018, the EPA approved Kentucky's proposed state implementation plan finding that no additional reductions beyond existing and planned controls set forth in Kentucky's existing State Implementation Plan are necessary to prevent Kentucky from contributing significantly to any other state’s nonattainment. In September 2018, the EPA denied petitions filed by Maryland and Delaware and in September 2019, denied a petition filed by New York alleging that states including Kentucky and Pennsylvania contribute to nonattainment in the petitioning states. PPL, LKE, LG&E and KU are unable to predict the outcome of ongoing and future evaluations by the EPA and the states, or whether such evaluations could potentially result in requirements for nitrogen oxide reductions beyond those currently required under the Cross-State Air Pollution Rule.

~~Climate Change~~

There is continuing world-wide attention focused on issues related to climate change. In June 2016, President Obama announced that the United States, Canada and Mexico established the North American Climate, Clean Energy, and Environment Partnership Plan, which specifies actions to promote clean energy, address climate change and protect the environment. The plan includes a goal to provide 50% of the energy used in North America from clean energy sources by 2025. The plan does not impose any nation-specific requirements.

In December 2015, 195 nations, including the U.S., signed the Paris Agreement on Climate, which establishes a comprehensive framework for the reduction of GHG emissions from both developed and developing nations. Although the agreement does not establish binding reduction requirements, it requires each nation to prepare, communicate, and maintain GHG reduction commitments. Reductions can be achieved in a variety of ways, including energy conservation, power plant efficiency improvements, reduced utilization of coal-fired generation or replacing coal-fired generation with natural gas or renewable generation. Based on the EPA's rules issued in 2015 imposing GHG emission standards for both new and existing power plants, the U.S. committed to an initial reduction target of 26% to 28% below 2005 levels by 2025. However, on June 1, 2017, President Trump announced a plan to withdraw from the Paris Agreement and undertake negotiations to reenter the current agreement or enter a new agreement on terms more favorable to the U.S. Under the terms of the Paris Agreement, any U.S. withdrawal would not be complete until November 2020. PPL, LKE, LG&E and KU cannot predict the outcome of such regulatory actions or the impact, if any, on plant operations, rate treatment or future capital or operating needs.

The U.K. has enacted binding carbon reduction requirements that are applicable to WPD. WPD is subject to requirements under the Streamlined Energy and Carbon Reporting framework along with a tax (called “Climate Change Levy”). The cost of the tax is not significant and is included in WPD’s operating expenses.

~~The EPA's Affordable Clean Energy Rule~~

In 2015, the EPA finalized rules imposing stringent GHG emission standards for both new and existing power plants based on plant specific energy efficiency upgrades, fuel switching from coal to natural gas, and deployment of renewable generation (the Clean Power Plan).

Following legal challenges to the Clean Power Plan, a stay of those rules by the U.S. Supreme Court and the March 2017 Executive Order requiring the EPA to review the Clean Power Plan, in October 2017, the EPA proposed to rescind the Clean Power Plan. In July 2019, the EPA rescinded the Clean Power Plan and finalized the Affordable Clean Energy (ACE) Rule as a replacement with respect to existing sources. The ACE Rule gives states broad latitude in establishing emission guidelines providing for plant-specific efficiency upgrades or "heat-rate improvements" that will reduce GHG emissions per unit of electricity generated. The ACE Rule provides a list of "candidate technologies" that will be considered by the states in

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establishing standards of performance on a case by case basis at individual power plants. States are generally allowed three years to submit state plans establishing standards of performance. While compliance deadlines will be imposed on a plant-specific basis, the EPA anticipates that most facilities will be required to demonstrate compliance within two years of plan approval. In the final rule, the EPA did not finalize its proposed new criteria for determining whether such efficiency projects would trigger New Source Review and thus be subject to more stringent emission controls. Instead, the agency intends to take final action on the proposed New Source Review revisions in a separate final action at a later date. Various entities have filed petitions for review and petitions for reconsideration. PPL, LKE, LG&E and KU cannot predict the outcome of the pending litigation and regulatory proceedings.

The Kentucky General Assembly passed legislation in April 2014 limiting the measures that the Kentucky Energy and Environment Cabinet may consider in setting performance standards to comply with federal requirements for GHG emission reductions. The legislation provides that such state GHG performance standards will be strictly based on emission reductions, efficiency measures and other improvements available at each power plant. These statutory restrictions are broadly consistent with the EPA's ACE Rule.

LG&E and KU are monitoring developments at the state and federal level. Until legal challenges and regulatory determinations relating to repeal and replacement of the Clean Power Plan are completed and the state determines implementation measures, PPL, LKE, LG&E and KU cannot predict the potential impact, if any, on plant operations, future capital or operating costs. PPL, LKE, LG&E and KU believe that the costs, which could be significant, would be subject to rate recovery.

~~Sulfuric Acid Mist Emissions~~ ~~(PPL, LKE and LG&E)~~

In June 2016, the EPA issued a notice of violation under the Clean Air Act alleging that LG&E violated applicable rules relating to sulfuric acid mist emissions at its Mill Creek plant. The notice alleges failure to install proper controls, failure to operate the facility consistent with good air pollution control practice, and causing emissions exceeding applicable requirements or constituting a nuisance or endangerment. LG&E believes it has complied with applicable regulations during the relevant time period. Discussions between the EPA and LG&E are ongoing. The parties have entered into a tolling agreement with respect to this matter through January 31, 2020. The parties are conducting initial negotiations regarding potential settlement of the matter. PPL, LKE and LG&E are unable to predict the outcome of this matter or the potential impact on operations of the Mill Creek plant, including increased capital or operating costs, and potential civil penalties or remedial measures, if any.

~~Water/Waste~~

~~(PPL, LKE, LG&E and KU)~~

~~CCRs~~

In April 2015, the EPA published its final rule regulating CCRs. CCRs include fly ash, bottom ash and sulfur dioxide scrubber wastes. The rule became effective in October 2015. It imposes extensive new requirements, including location restrictions, design and operating standards, groundwater monitoring and corrective action requirements, and closure and post-closure care requirements on CCR impoundments and landfills that are not already closed and located on active power plants in the United States. Under the rule, CCRs are regulated as non-hazardous under Subtitle D of RCRA and beneficial use of CCRs is allowed, with some restrictions. The rule's requirements for covered CCR impoundments and landfills include implementation of groundwater monitoring and commencement or completion of closure activities generally between three and ten years from certain triggering events. The rule requires posting of compliance documentation on a publicly accessible website. Industry groups, environmental groups, individual companies and others have filed legal challenges to the final rule, which are pending before the D.C. Circuit Court of Appeals. In March 2018, the EPA proposed amendments to the CCR rule primarily relating to impoundment closure and remediation requirements. In July 2018, the EPA published in the Federal Register a final rule extending the deadline for closure of certain impoundments to October 2020 and adopting substantive changes relating to certifications, suspensions of groundwater monitoring and groundwater protection standards for certain constituents. In July 2019, the EPA released proposed amendments to the CCR Rule relating to reporting, public information, boron standards, beneficial use and waste piles. The EPA released additional proposed amendments to the rule on November 4, 2019, with further proposed amendments expected in the future. In August 2018, the D.C. Circuit Court of Appeals vacated and remanded portions of the CCR rule including provisions allowing unlined impoundments to continue operating and exempting inactive impoundments at inactive plants from regulation. As a result of subsequent challenges to the CCR Rule amendments, on March 13, 2019, the D.C. Circuit Court granted the EPA’s motion for voluntary remand of the amended rule without voiding it. Consequently, the CCR Rule amendments, including the extended compliance deadline, will remain in place as the EPA considers further rule amendments and revisions. PPL, LKE, LG&E and KU are unable to predict the outcome of the ongoing

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rulemaking or potential impacts on current LG&E and KU compliance plans. Associated costs are expected to be subject to rate recovery. The Registrants are currently finalizing closure plans and schedules.

In January 2017, the Kentucky Energy and Environment Cabinet issued a new state rule relating to CCR management aimed at reflecting the requirements of the federal CCR rule. As a result of a subsequent legal challenge in January 2018, the Franklin County, Kentucky Court issued an opinion invalidating certain procedural elements of the rule. LG&E and KU presently operate their facilities under continuing permits authorized under the former program and do not currently anticipate material impacts as a result of the judicial ruling. The Kentucky Energy and Environmental Cabinet has announced it expects to propose new state rules in 2019 aimed at addressing the procedural deficiencies identified by the court and providing the regulatory framework necessary for operation of the state CCR program in lieu of the federal CCR Rule, as provided by applicable law. Associated costs are expected to be subject to rate recovery.

LG&E and KU received KPSC approval for a compliance plan providing for the closure of impoundments at the Mill Creek, Trimble County, E.W. Brown, and Ghent stations, and construction of process water management facilities at those plants. In addition to the foregoing measures required for compliance with the federal CCR rule, KU also received KPSC approval for its plans to close impoundments at the retired Green River, Pineville and Tyrone plants to comply with applicable state law. Since 2017, LG&E and KU have commenced closure of many of the subject impoundments and have completed closure of some of the smaller impoundments. LG&E and KU expect to commence closure of the remaining impoundments no later than October 31, 2020. LG&E and KU generally expect to complete impoundment closures within five years of commencement, although a longer period may be required to complete closure of some facilities. Associated costs are expected to be subject to rate recovery.

In connection with the final CCR rule, LG&E and KU recorded adjustments to existing AROs beginning in 2015 and continue to record adjustments as required. See Note 16 below and Note 19 in the Registrants' 2018 Form 10-K for additional information. Further changes to AROs, current capital plans or operating costs may be required as estimates are refined based on closure developments, groundwater monitoring results, and regulatory or legal proceedings. Costs relating to this rule are subject to rate recovery.

~~Clean Water Act~~

Regulations under the federal Clean Water Act dictate permitting and mitigation requirements for facilities and construction projects in the United States. Many of those requirements relate to power plant operations, including requirements related to the treatment of pollutants in effluents prior to discharge, the temperature of effluent discharges and the location, design and construction of cooling water intake structures at generating facilities, standards intended to protect aquatic organisms that become trapped at or pulled through cooling water intake structures at generating facilities. The requirements could impose significant costs for LG&E and KU, which are subject to rate recovery.

~~Clean Water Act Jurisdiction~~

For several years the EPA has been seeking to clarify which discharges are subject to the Clean Water Act. The issue is primarily significant to PPL's operations with respect to discharges to groundwater from ash basins. There has been substantial disagreement over whether Clean Water Act jurisdiction covers discharges of contaminants to groundwater which reach surface water via a direct hydrologic connection. In particular, various environmental groups and other stakeholders argue that leaking impoundments located at coal-fired power plants are subject to Clean Water Act jurisdiction, while facility owners and many states contend that such situations are more appropriately addressed under the EPA's CCR Rule and state regulatory programs.

Most recently, on April 12, 2019, the EPA released an interpretive statement concluding that Clean Water Act jurisdiction does not cover discharges to groundwater regardless of any hydrologic connection between groundwater and jurisdictional surface water.

~~The issue has been subject to extensive litigation in federal courts including the citizen suit filed against KU with respect to its E.W. Brown plant,~~as discussed under “Legal Matters” - “E.W. Brown Environmental Claims” above, resulting in contradictory rulings by courts in different jurisdictions. On February 19, 2019, the U.S. Supreme Court agreed to review a lower court ruling on the issue. The U.S. Supreme Court’s ruling in that case, likely to be issued in the first half of 2020, is expected to provide additional clarification on the scope of Clean Water Act jurisdiction. Extending Clean Water Act jurisdiction to such discharges could potentially subject certain releases from CCR impoundments to additional permitting and remediation requirements.

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~~PPL, LKE, LG&E and KU are unable to predict the outcome of current or future regulatory proceedings or litigation or potential impacts on current LG&E and KU compliance plans.~~

~~ELGs~~

In September 2015, the EPA released its final ELGs for wastewater discharge permits for new and existing steam electric generating facilities. The rule provides strict technology-based discharge limitations for control of pollutants in scrubber wastewater, fly ash and bottom ash transport water, mercury control wastewater, gasification wastewater and combustion residual leachate. The new guidelines require deployment of additional control technologies providing physical, chemical and biological treatment of wastewaters. The guidelines also mandate operational changes including "no discharge" requirements for fly ash and bottom ash transport waters and mercury control wastewaters. The implementation date for individual generating stations will be determined by the states on a case-by-case basis according to criteria provided by the EPA. Industry groups, environmental groups, individual companies and others have filed legal challenges to the final rule, which have been consolidated before the U.S. Court of Appeals for the Fifth Circuit. In April 2017, the EPA announced that it would grant petitions for reconsideration of the rule. In September 2017, the EPA published in the Federal Register a proposed rule that would postpone the compliance date for requirements relating to bottom ash transport waters and scrubber wastewaters discharge limits. The proposed rule is expected to be finalized by the end of 2019. On April 12, 2019, the U.S. Court of Appeals for the Fifth Circuit vacated and remanded portions of the ELGs concerning legacy wastewater and CCR leachate. The EPA released proposed rules on November 4, 2019 and expects to complete its reconsideration of best available technology standards by the fall of 2020. Upon completion of the ongoing regulatory proceedings, the rule will be implemented by the states in the course of their normal permitting activities. LG&E and KU are developing compliance strategies and schedules. PPL, LKE, LG&E and KU are unable to predict the outcome of the EPA's pending reconsideration of the rule or fully estimate compliance costs or timing. Additionally, certain aspects of these compliance plans and estimates relate to developments in state water quality standards, which are separate from the ELG rule or its implementation. Costs to comply with ELGs or other discharge limits are expected to be significant. Certain costs are included in the Registrants’ capital plans and are subject to rate recovery.

~~Seepages and Groundwater Infiltration~~

In addition to the actions described above, LG&E and KU have completed, or are completing, assessments of seepages or groundwater infiltration at various facilities and have completed, or are working with agencies to implement, further testing, monitoring or abatement measures, where applicable. Depending on the circumstances in each case, certain costs, which may be subject to rate recovery, could be significant. LG&E and KU cannot currently estimate a possible loss or range of possible losses related to this matter.

~~(PPL Electric, LG&E and KU)~~

~~Superfund and Other Remediation~~

PPL Electric, LG&E and KU are potentially responsible for investigating, responding to agency inquiries, implementing various preventative measures, and/or remediating contamination under programs other than those described in the sections above. These include a number of former coal gas manufacturing plants in Pennsylvania and Kentucky previously owned or operated or currently owned by predecessors or affiliates of PPL Electric, LG&E and KU. To date, the costs of these sites have not been significant.

There are additional sites formerly owned or operated by PPL Electric, LG&E and KU predecessors or affiliates. PPL Electric, LG&E and KU lack sufficient information about such additional sites to estimate any potential liability they may have or a range of reasonably possible losses, if any, related to these matters.

PPL Electric is potentially responsible for a share of the costs at several sites listed by the EPA under the federal Superfund program, including the Columbia Gas Plant site and the Brodhead site. Clean-up actions have been or are being undertaken at all of these sites, the costs of which have not been, and are not expected to be, significant to PPL Electric.

The EPA is evaluating the risks associated with polycyclic aromatic hydrocarbons and naphthalene, chemical by-products of coal gas manufacturing. As a result of the EPA's evaluation, individual states may establish stricter standards for water quality and soil cleanup. This could require several PPL subsidiaries to take more extensive assessment and remedial actions at former coal gas manufacturing plants. PPL, PPL Electric, LKE, LG&E and KU cannot estimate a range of reasonably possible losses, if any, related to these matters.

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From time to time, PPL's subsidiaries in the United States undertake testing, monitoring or remedial action in response to notices of violations, spills or other releases at various on-site and off-site locations, negotiate with the EPA and state and local agencies regarding actions necessary to comply with applicable requirements, negotiate with property owners and other third parties alleging impacts from PPL's operations and undertake similar actions necessary to resolve environmental matters that arise in the course of normal operations. Based on analyses to date, resolution of these environmental matters is not expected to have a significant adverse impact on the operations of PPL Electric, LG&E and KU.

PPL Electric had a recorded liability of $11 million at September 30, 2019 and December 31, 2018 representing its best estimate of the probable loss incurred to remediate the sites noted in this section. Depending on the outcome of investigations at sites where investigations have not begun or been completed, or developments at sites for which information is incomplete, additional costs of remediation could be incurred; however, such costs are not expected to be significant.

Future cleanup or remediation work at sites not yet identified may result in significant additional costs for PPL, PPL Electric, LKE, LG&E and KU. Insurance policies maintained by LKE, LG&E and KU may be available to cover certain costs or other obligations related to these matters, but the amount of insurance coverage or reimbursement cannot be estimated or assured.

Other

Guarantees and Other Assurances

(All Registrants)

In the normal course of business, the Registrants enter into agreements that provide financial performance assurance to third parties on behalf of certain subsidiaries. Such agreements include, for example, guarantees, stand-by letters of credit issued by financial institutions and surety bonds issued by insurance companies. These agreements are entered into primarily to support or enhance the creditworthiness attributed to a subsidiary on a stand-alone basis or to facilitate the commercial activities in which these subsidiaries engage.

(PPL)

PPL fully and unconditionally guarantees all of the debt securities of PPL Capital Funding.

(All Registrants)

The table below details guarantees provided as of ~~September 30, 2019.~~March 31, 2020. "Exposure" represents the estimated maximum potential amount of future payments that could be required to be made under the guarantee. The probability of expected payment/performance under each of these guarantees is remote except for "WPD guarantee of pension and other obligations of unconsolidated entities," for which PPL has a total recorded liability of $5 million at ~~September 30, 2019~~March 31, 2020 and ~~$6 million at~~ December 31, ~~2018.~~2019. For reporting purposes, on a consolidated basis, all guarantees of PPL Electric, LKE, LG&E and KU also apply to PPL, and all guarantees of LG&E and KU also apply to LKE.

Exposure at
September 30, 2019 Expiration
Date
PPL
Indemnifications related to the WPD Midlands acquisition (a)
WPD indemnifications for entities in liquidation and sales of assets $ 10
(b) 2021
WPD guarantee of pension and other obligations of unconsolidated entities 77
(c)

PPL Electric
Guarantee of inventory value 26
(d) 2020

LKE
Indemnification of lease termination and other divestitures 200
(e) 2021

LG&E and KU
LG&E and KU obligation of shortfall related to OVEC (f)

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	Exposure at March 31, 2020			Expiration Date
PPL
Indemnifications related to the WPD Midlands acquisition			(a)
WPD indemnifications for entities in liquidation and sales of assets	$	10	(b)	2022
WPD guarantee of pension and other obligations of unconsolidated entities	77		(c)
PPL Electric
Guarantee of inventory value	6		(d)	2020
LKE
Indemnification of lease termination and other divestitures	200		(e)	2021
LG&E and KU
LG&E and KU obligation of shortfall related to OVEC			(f)

(a)

Indemnifications related to certain liabilities, including a specific unresolved tax issue and those relating to properties and assets owned by the seller that were transferred to WPD Midlands in connection with the acquisition. A cross indemnity has been received from the seller on the tax issue. The maximum exposure and expiration of these indemnifications cannot be estimated because the maximum potential liability is not capped and the expiration date is not specified in the transaction documents.

(b)

Indemnification to the liquidators and certain others for existing liabilities or expenses or liabilities arising during the liquidation process. The indemnifications are limited to distributions made from the subsidiary to its parent either prior or subsequent to liquidation or are not explicitly stated in the agreements. The indemnifications generally expire 2 to 7 years subsequent to the date of dissolution of the entities. The exposure noted only includes those cases where the agreements provide for specific limits.

In connection with their sales of various businesses, WPD and its affiliates have provided the purchasers with indemnifications that are standard for such transactions, including indemnifications for certain pre-existing liabilities and environmental and tax matters or have agreed to continue their obligations under existing third-party guarantees, either for a set period of time following the transactions or upon the condition that the purchasers make reasonable efforts to terminate the guarantees. Additionally, WPD and its affiliates remain secondarily responsible for lease payments under certain leases that they have assigned to third parties.

(c)

Relates to certain obligations of discontinued or modified electric associations that were guaranteed at the time of privatization by the participating members. Costs are allocated to the members and can be reallocated if an existing member becomes insolvent. At ~~September 30, 2019,~~March 31, 2020, WPD has recorded an estimated discounted liability for which the expected payment/performance is probable. Neither the expiration date nor the maximum amount of potential payments for certain obligations is explicitly stated in the related agreements, and as a result, the exposure has been estimated.


(d)	A third-party logistics firm ~~provides~~provided inventory procurement and fulfillment ~~services.~~services, whose contract was terminated as of March 2020. The logistics firm has title to the inventory, however, upon termination of the contracts, PPL Electric has guaranteed to purchase any remaining inventory that has not been used or sold.

(e)

LKE provides certain indemnifications covering the due and punctual payment, performance and discharge by each party of its respective obligations. The most comprehensive of these guarantees is the LKE guarantee covering operational, regulatory and environmental commitments and indemnifications made by WKE under a 2009 Transaction Termination Agreement. This guarantee has a term of 12 years ending July 2021, and a maximum exposure of $200 million, exclusive of certain items such as government fines and penalties that may exceed the maximum. Additionally, LKE has indemnified various third parties related to historical obligations for other divested subsidiaries and affiliates. The indemnifications vary by entity and the maximum exposures range from being capped at the sale price to no specified maximum. LKE could be required to perform on these indemnifications in the event of covered losses or liabilities being claimed by an indemnified party. LKE cannot predict the ultimate outcomes of the various indemnification scenarios, but does not expect such outcomes to result in significant losses above the amounts recorded.

(f)

Pursuant to the OVEC power purchase contract, LG&E and KU are obligated to pay for their share of OVEC's excess debt service, post-retirement and decommissioning costs, as well as any shortfall from amounts included within a demand charge designed and expected to cover these costs over the term of the contract. LKE's proportionate share of OVEC's outstanding debt was ~~$111~~$109 million at ~~September 30, 2019,~~March 31, 2020, consisting of LG&E's share of ~~$77~~$76 million and KU's share of ~~$34~~$33 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" in Note 13 in PPL's, LKE's, LG&E's and KU's ~~2018~~2019 Form 10-K for additional information on the OVEC power purchase contract.

In March 2018, a ~~co-sponsor~~sponsor with a 4.85% pro-rata share of ~~certain~~ OVEC obligations ~~of 4.85%~~ filed for bankruptcy under Chapter 11 and, in August 2018, received a rejection order for the OVEC power purchase contract in the bankruptcy proceeding. In October 2019, the bankruptcy court issued an order confirming the ~~co-sponsor's~~sponsor's proposed reorganization plan. OVEC and other entities are challenging the contract rejection, the bankruptcy plan confirmation and regulatory aspects of the plan in various forums. In December 2019, an appellate court remanded the contract rejection issue and in March 2020 the FERC commenced a related proceeding. The ~~plan's~~plan was declared effective ~~date remains~~in February 2020, but certain aspects of the matter are subject to ~~certain conditions precedent,~~the on-going appellate, bankruptcy and regulatory proceedings, including ~~remaining~~issues relating to the appropriateness of the rejection of the OVEC power purchase agreement and regulatory ~~approvals, and to relevant current or future appellate rights or proceedings.~~appropriateness of the plan's confirmation. Periodically, OVEC and certain of its sponsors, including LG&E and KU, ~~are analyzing~~consider certain potential additional credit support actions to preserve OVEC's access to credit markets or mitigate risks or adverse impacts relating thereto, including addressing increased interest costs, establishing or continuing debt reserve accounts or other changes involving OVEC's existing short and long-term debt. The ultimate outcome of these matters, including the ~~co-sponsor~~sponsor bankruptcy and related appellate or regulatory proceedings, ~~and challenges~~OVEC structural or financial steps relating thereto and any other potential impact on LG&E's and KU's obligations relating to OVEC ~~debt~~ under the power purchase contract cannot be predicted.

The Registrants provide other miscellaneous guarantees through contracts entered into in the normal course of business. These guarantees are primarily in the form of indemnification or warranties related to services or equipment and vary in duration. The amounts of these guarantees often are not explicitly stated, and the overall maximum amount of the obligation under such

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guarantees cannot be reasonably estimated. Historically, no significant payments have been made with respect to these types of guarantees and the ~~Registrants believe the~~ probability of payment/performance under these guarantees is remote.

PPL, on behalf of itself and certain of its subsidiaries, maintains insurance that covers liability assumed under contract for bodily injury and property damage. The coverage provides maximum aggregate coverage of $225 million. This insurance may be applicable to obligations under certain of these contractual arrangements.

Risks and Uncertainties(All Registrants)

The COVID-19 pandemic has disrupted the U.S. and global economies and continues to present extraordinary challenges to businesses, communities, workforces and markets. In the U.S. and throughout the world, governmental authorities have taken urgent and extensive actions to contain the spread of the virus and mitigate known or foreseeable impacts. In the Registrants’ service territories, mitigation measures have included quarantines, stay-at-home orders, travel restrictions, reduced operations or closures of businesses, schools and governmental agencies, and legislative or regulatory actions to address health or other pandemic-related concerns, all of which have the potential to adversely impact the Registrants' business and operations, especially if these measures remain in effect for a prolonged period of time.

To date, the Registrants have not experienced a significant impact on their business, results of operations, financial condition, liquidity, operations or on their supply chain as a result of COVID-19; however, the duration and severity of the outbreak and its ultimate effects on the global economy, the financial markets, or the Registrants’ workforce, customers and suppliers are uncertain. A protracted slowdown of broad sectors of the economy, prolonged or pervasive restrictions on businesses and their workforces, or significant changes in legislation or regulatory policy to address the COVID-19 pandemic all present significant risks to the Registrants. These or other unpredictable events resulting from the pandemic could further reduce customer demand for electricity and gas, impact the Registrants’ employees and supply chains, result in an increase in certain costs, delay payments or increase bad debts, or result in changes in the fair value of their assets and liabilities, which could materially and adversely affect the Registrants’ business, results of operations, financial condition or liquidity.

~~12.~~11. Related Party Transactions

Support Costs (PPL Electric, LKE, LG&E and KU)

PPL Services, PPL EU Services and LKS provide PPL, PPL Electric, LKE, their respective subsidiaries, including LG&E and KU, and each other with administrative, management and support services. For all services companies, the costs of directly assignable and attributable services are charged to the respective recipients as direct support costs. General costs that cannot be directly assigned or attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. PPL Services may also use a ratio of overall direct and indirect costs or a weighted average cost ratio. LKS bases its indirect allocations on the subsidiaries' number of employees, total assets, revenues, number of customers and/or other statistical information. PPL Services, PPL EU Services

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and LKS charged the following amounts for the periods ended ~~September 30,~~March 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable.


	Three Months				Nine Months				Three Months
	2019		2018		2019		2018		2020		2019
PPL Electric from PPL Services	$	14	$	14	$	43	$	45	$	12	$	16
LKE from PPL Services	6		5		20		19		6		9
PPL Electric from PPL EU Services	38		34		112		110		41		37
LG&E from LKS	37		36		112		113		38		38
KU from LKS	42		42		126		127		41		43

In addition to the charges for services noted above, LKS makes payments on behalf of LG&E and KU for fuel purchases and other costs for products or services provided by third parties. LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between LKE and LG&E and KU are reimbursed through LKS.

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Intercompany Borrowings

(PPL Electric)

PPL Energy Funding maintains a $650 million revolving line of credit with a PPL Electric subsidiary. ~~At September 30, 2019, $546 million was outstanding and reflected in "Notes receivable from affiliate" on the Balance Sheet.~~ NaN balance was outstanding at March 31, 2020 and December 31, ~~2018.~~2019. The interest rates on borrowings are equal to one-month LIBOR plus a spread. ~~The interest rate on the outstanding borrowing at September 30, 2019 was 3.84% and~~Interest income is reflected in "Interest Income from Affiliate" on the ~~Statements of Income.~~Income Statements.

(LKE)

LKE maintains a $375 million revolving line of credit with a PPL Energy Funding subsidiary whereby LKE can borrow funds on a short-term basis at market-based rates. The interest rates on borrowings are equal to one-month LIBOR plus a spread. At ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018, $129~~2019, $242 million and ~~$113~~$150 million were outstanding and reflected in "Notes payable with affiliates" on the Balance Sheets. The interest rates on the outstanding borrowings at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018~~2019 were ~~3.59%~~3.02% and ~~3.85%~~3.20%. Interest expense on the revolving line of credit was not significant for the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 and ~~2018.~~2019.

LKE maintains an agreement with a PPL affiliate that has a $300 million borrowing limit whereby LKE can loan funds on a short-term basis at market-based rates. NaN balance was outstanding at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018.~~2019. The interest rate on the loan is based on the PPL affiliate's credit rating and equal to one-month LIBOR plus a spread.

LKE maintains ten-year notes of $400 million and $250 million with a PPL affiliate with interest rates of 3.5% and 4%. At ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, the notes were reflected in "Long-term debt to affiliate" on the Balance Sheets. Interest expense on the $400 million note was $4 million ~~and $11 million~~ for the three months ending March 31, 2020 and ~~nine months ended September 30, 2019 and 2018.~~2019. Interest expense on the $250 million note was $3 million ~~and $8 million~~ for the three months ending March 31, 2020 and ~~nine months ended September 30, 2019~~2019.

(LG&E)

LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to $500 million at an interest rate based on a market index of commercial paper issues. At March 31, 2020, LG&E had borrowings outstanding from KU in the amount of $21 million. This balance is reflected in “Notes payable with affiliates” on the Balance Sheets. NaN balances were outstanding at December 31, 2019.

(KU)

KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to $500 million at an interest rate based on a market index of commercial paper issues. NaN balances were outstanding at March 31, 2020 and ~~$3 million and $4 million for the three and nine months ended September 30, 2018.~~December 31, 2019.

VEBA Funds Receivable (PPL Electric)

In May 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay medical claims of active bargaining unit employees. Based on PPL Electric's participation in PPL’s Other Postretirement Benefit plan, PPL Electric was allocated a portion of the excess funds from PPL Services. These funds have been recorded as an intercompany receivable on PPL Electric's Balance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. The intercompany receivable balance associated with these funds was ~~$37~~$32 million as of ~~September 30,~~March 31, 2020 and December 31, 2019, of which $10 million was reflected in "Accounts receivable from affiliates" and ~~$27~~$22 million was reflected in "Other noncurrent assets" on the PPL Electric Balance Sheet. The intercompany receivable balance associated with these funds was $45 million as of December 31, 2018, of which $10 million was reflected in "Account receivable from affiliates" and $35 million was reflected in "Other noncurrent assets" on the PPL Electric Balance Sheets.

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Other (PPL Electric, LG&E and KU)

See Note 109 for discussions regarding intercompany allocations associated with defined benefits.

~~13.~~Table of Contents

12. Other Income (Expense) - net

~~(PPL)~~

~~The details of "Other Income (Expense) - net" for the periods ended September 30, were:~~

Three Months Nine Months
2019 2018 2019 2018
Other Income

Economic foreign currency exchange contracts (Note 15) $ 44
$ 40
$ 56
$ 92
Defined benefit plans - non-service credits (Note 10) 77
61
237
195
Interest income 3
3
12
5
AFUDC - equity component 6
5
17
15
Miscellaneous 1
2
6
3
Total Other Income 131
111
328
310
Other Expense

Charitable contributions 1
1
3
6
Miscellaneous 4
4
16
7
Total Other Expense 5
5
19
13
Other Income (Expense) - net $ 126
$ 106
$ 309
$ 297

~~(PPL Electric)~~(PPL)

The details of "Other Income (Expense) - net" for the periods ended ~~September 30,~~March 31, were:


	Three Months				Nine Months				Three Months
	2019		2018		2019		2018		2020		2019
Other Income
Economic foreign currency exchange contracts (Note 14)									$	62	$	(33	)
Defined benefit plans - non-service credits (Note 9)									68		80
Interest income									1		6
AFUDC - equity component	$	6	$	5	$	17	$	15	3		5
Defined benefit plans - non-service credits (Note 10)	1		1		3		4
Interest income	—		—		1		—
Miscellaneous	—		—		—		1		1		6
Total Other Income	7		6		21		20		135		64
Other Expense
Charitable contributions	—		1		2		2		1		2
Miscellaneous	—		—		1		—		9		10
Total Other Expense	—		1		3		2		10		12
Other Income (Expense) - net	$	7	$	5	$	18	$	18	$	125	$	52

~~14.~~13. Fair Value Measurements

(All Registrants)

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (an exit price). A market approach (generally, data from market transactions), an income approach (generally, present value techniques and option-pricing models) and/or a cost approach (generally, replacement cost) are used to measure the fair value of an asset or liability, as appropriate. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk. The fair value of a group of financial assets

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and liabilities is measured on a net basis. See Note 1 in each Registrant's ~~2018~~2019 Form 10-K for information on the levels in the fair value hierarchy.

Recurring Fair Value Measurements

The assets and liabilities measured at fair value were:

September 30, 2019 December 31, 2018
Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3
PPL

Assets
Cash and cash equivalents $ 670
$ 670
$ —
$ —
$ 621
$ 621
$ —
$ —
Restricted cash and cash equivalents (a) 20
20
—
—
22
22
—
—
Special use funds (a):
Money market fund 2
2
—
—
59
59
—
—
Commingled debt fund measured at NAV (b) 29
—
—
—
—
—
—
—
Commingled equity fund measured at NAV (b) 28
—
—
—
—
—
—
—
Total special use funds 59
2
—
—
59
59
—
—
Price risk management assets (c):

Foreign currency contracts 224
—
224
—
202
—
202
—
Cross-currency swaps 195
—
195
—
135
—
135
—
Total price risk management assets 419
—
419
—
337
—
337
—
Total assets $ 1,168
$ 692
$ 419
$ —
$ 1,039
$ 702
$ 337
$ —

Liabilities

Price risk management liabilities (c):

Interest rate swaps $ 25
$ —
$ 25
$ —
$ 20
$ —
$ 20
$ —
Foreign currency contracts 3
—
3
—
2
—
2
—
Total price risk management liabilities $ 28
$ —
$ 28
$ —
$ 22
$ —
$ 22
$ —

PPL Electric

Assets

Cash and cash equivalents $ 27
$ 27
$ —
$ —
$ 267
$ 267
$ —
$ —
Restricted cash and cash equivalents (a) 2
2
—
—
2
2
—
—
Total assets $ 29
$ 29
$ —
$ —
$ 269
$ 269
$ —
$ —

LKE

Assets
Cash and cash equivalents $ 30
$ 30
$ —
$ —
$ 24
$ 24
$ —
$ —
Total assets $ 30
$ 30
$ —
$ —
$ 24
$ 24
$ —
$ —

Liabilities

Price risk management liabilities:

Interest rate swaps $ 25
$ —
$ 25
$ —
$ 20
$ —
$ 20
$ —
Total price risk management liabilities $ 25
$ —
$ 25
$ —
$ 20
$ —
$ 20
$ —

LG&E

Assets

Cash and cash equivalents $ 12
$ 12
$ —
$ —
$ 10
$ 10
$ —
$ —
Total assets $ 12
$ 12
$ —
$ —
$ 10
$ 10
$ —
$ —



	March 31, 2020								December 31, 2019
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
PPL
Assets
Cash and cash equivalents	$	915	$	915	$	—	$	—	$	815	$	815	$	—	$	—
Restricted cash and cash equivalents (a)	21		21		—		—		21		21		—		—
Special use funds (a):
Money market fund	1		1		—		—		—		—		—		—
Commingled debt fund measured at NAV (b)	29		—		—		—		29		—		—		—
Commingled equity fund measured at NAV (b)	22		—		—		—		27		—		—		—
Total special use funds	52		1		—		—		56		—		—		—

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	September 30, 2019								December 31, 2018								March 31, 2020								December 31, 2019
																	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
Price risk management assets (c):
Foreign currency contracts																	190		—		190		—		142		—		142		—
Cross-currency swaps																	169		—		169		—		154		—		154		—
Total price risk management assets																	359		—		359		—		296		—		296		—
Total assets																	$	1,347	$	937	$	359	$	—	$	1,188	$	836	$	296	$	—

Liabilities
Price risk management liabilities (c):
Interest rate swaps																	$	34	$	—	$	34	$	—	$	21	$	—	$	21	$	—
Foreign currency contracts																	—		—		—		—		5		—		5		—
Total price risk management liabilities																	$	34	$	—	$	34	$	—	$	26	$	—	$	26	$	—

PPL Electric
Assets
Cash and cash equivalents																	$	33	$	33	$	—	$	—	$	262	$	262	$	—	$	—
Restricted cash and cash equivalents (a)																	2		2		—		—		2		2		—		—
Total assets																	$	35	$	35	$	—	$	—	$	264	$	264	$	—	$	—

LKE
Assets
Cash and cash equivalents																	$	47	$	47	$	—	$	—	$	27	$	27	$	—	$	—
Cash collateral posted to counterparties (d)																	1		1		—		—		—		—		—		—
Total assets																	$	48	$	48	$	—	$	—	$	27	$	27	$	—	$	—

Liabilities
Price risk management liabilities:
Interest rate swaps																	$	29	$	—	$	29	$	—	$	21	$	—	$	21	$	—
Total price risk management liabilities																	$	29	$	—	$	29	$	—	$	21	$	—	$	21	$	—

LG&E
Assets
Cash and cash equivalents																	$	7	$	7	$	—	$	—	$	15	$	15	$	—	$	—
Cash collateral posted to counterparties (d)																	1		1		—		—		—		—		—		—
Total assets																	$	8	$	8	$	—	$	—	$	15	$	15	$	—	$	—
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
Liabilities
Price risk management liabilities:
Interest rate swaps	$	25	$	—	$	25	$	—	$	20	$	—	$	20	$	—	$	29	$	—	$	29	$	—	$	21	$	—	$	21	$	—
Total price risk management liabilities	$	25	$	—	$	25	$	—	$	20	$	—	$	20	$	—	$	29	$	—	$	29	$	—	$	21	$	—	$	21	$	—

KU
Assets
Cash and cash equivalents	$	18	$	18	$	—	$	—	$	14	$	14	$	—	$	—	$	40	$	40	$	—	$	—	$	12	$	12	$	—	$	—
Total assets	$	18	$	18	$	—	$	—	$	14	$	14	$	—	$	—	$	40	$	40	$	—	$	—	$	12	$	12	$	—	$	—


(a)	Current portion is included in "Other current assets" and long-term portion is included in "Other noncurrent assets" on the Balance Sheets.


(b)	In accordance with accounting guidance, certain investments that are measured at fair value using net asset value per share (NAV), or its equivalent, have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position.


(c)	Current portion is included in "Price risk management assets" and "Other current liabilities" and noncurrent portion is included in "Price risk management assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets.


(d)	Included in "Other noncurrent assets" on the Balance Sheets. Represents cash collateral posted to offset the exposure with counterparties related to certain interest rate swaps under master netting arrangements that are not offset.

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Special Use Funds

(PPL)

The special use funds are investments restricted for paying active union employee medical costs. In May 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA to be used to pay medical claims of active bargaining unit employees. ~~In 2019, the~~The funds are invested primarily in commingled debt and equity funds measured at ~~NAV. In 2018,~~NAV and are classified as investments in equity securities. Changes in fair value of the funds ~~were invested in money market funds.~~are recorded to the Statements of Income.

Price Risk Management Assets/Liabilities - Interest Rate Swaps/Foreign Currency Contracts/Cross-Currency Swaps

(PPL, LKE, LG&E and KU)

To manage interest rate risk, PPL, LKE, LG&E and KU use interest rate contracts such as forward-starting swaps, floating-to-fixed swaps and fixed-to-floating swaps. To manage foreign currency exchange risk, PPL uses foreign currency contracts such as forwards, options and cross-currency swaps that contain characteristics of both interest rate and foreign currency contracts. An income approach is used to measure the fair value of these contracts, utilizing readily observable inputs, such as forward interest rates (e.g., LIBOR and government security rates) and forward foreign currency exchange rates (e.g., GBP), as well as inputs that may not be observable, such as credit valuation adjustments. In certain cases, market information cannot practicably be obtained to value credit risk and therefore internal models are relied upon. These models use projected probabilities of default and estimated recovery rates based on historical observances. When the credit valuation adjustment is significant to the overall valuation, the contracts are classified as Level 3.

Financial Instruments Not Recorded at Fair Value (All Registrants)

The carrying amounts of long-term debt on the Balance Sheets and their estimated fair values are set forth below. Long-term debt is classified as Level 2. The effect of third-party credit enhancements is not included in the fair value measurement.


	September 30, 2019				December 31, 2018				March 31, 2020				December 31, 2019
	Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value
PPL	$	21,547	$	25,506	$	20,599	$	22,939	$	21,840	$	25,175	$	21,893	$	25,481
PPL Electric	4,085		4,764		3,694		3,901		3,986		4,500		3,985		4,589
LKE	6,001		6,901		5,502		5,768		6,003		6,774		6,002		6,766
LG&E	2,004		2,322		1,809		1,874		2,005		2,254		2,005		2,278
KU	2,623		3,064		2,321		2,451		2,624		2,978		2,623		3,003


(a)	Amounts are net of debt issuance costs.

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The carrying amounts of other current financial instruments (except for long-term debt due within one year) approximate their fair values because of their short-term nature.

~~15.~~14. Derivative Instruments and Hedging Activities

Risk Management Objectives

(All Registrants)

PPL has a risk management policy approved by the Board of Directors to manage market risk associated with commodities, interest rates on debt issuances and foreign exchange (including price, liquidity and volumetric risk) and credit risk (including non-performance risk and payment default risk). The Risk Management Committee, comprised of senior management and chaired by the Senior Director-Risk Management, oversees the risk management function. Key risk control activities designed to ensure compliance with the risk policy and detailed programs include, but are not limited to, credit review and approval, validation of transactions, verification of risk and transaction limits, value-at-risk analyses (VaR, a statistical model that attempts to estimate the value of potential loss over a given holding period under normal market conditions at a given confidence level) and the coordination and reporting of the Enterprise Risk Management program.

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Market Risk

Market risk includes the potential loss that may be incurred as a result of price changes associated with a particular financial or commodity instrument as well as market liquidity and volumetric risks. Forward contracts, futures contracts, options, swaps and structured transactions are utilized as part of risk management strategies to minimize unanticipated fluctuations in earnings caused by changes in commodity prices, interest rates and foreign currency exchange rates. Many of these contracts meet the definition of a derivative. All derivatives are recognized on the Balance Sheets at their fair value, unless NPNS is elected.

The following summarizes the market risks that affect PPL and its subsidiaries.

Interest Rate Risk

PPL and its subsidiaries are exposed to interest rate risk associated with forecasted fixed-rate and existing floating-rate debt issuances. PPL and WPD hold over-the-counter cross currency swaps to limit exposure to market fluctuations on interest and principal payments from changes in foreign currency exchange rates and interest rates. PPL, LKE and LG&E utilize over-the-counter interest rate swaps to limit exposure to market fluctuations on floating-rate debt. PPL, WPD, LKE, LG&E and KU utilize forward starting interest rate swaps to hedge changes in benchmark interest rates, when appropriate, in connection with future debt issuances.

PPL and its subsidiaries are exposed to interest rate risk associated with debt securities and derivatives held by defined benefit plans. This risk is significantly mitigated to the extent that the plans are sponsored at, or sponsored on behalf of, the regulated domestic utilities and for certain plans at WPD due to the recovery methods in place.

Foreign Currency Risk (PPL)

PPL is exposed to foreign currency exchange risk primarily associated with its investments in and earnings of U.K. affiliates.

(All Registrants)

Commodity Price Risk

PPL is exposed to commodity price risk through its domestic subsidiaries as described below.


•	PPL Electric is required to purchase electricity to fulfill its obligation as a PLR. Potential commodity price risk is insignificant and mitigated through its PUC-approved cost recovery mechanism and full-requirement supply agreements to serve its PLR customers which transfer the risk to energy suppliers.


•	LG&E's and KU's rates include certain mechanisms for fuel, fuel-related expenses and energy purchases. In addition, LG&E's rates include a mechanism for natural gas supply expenses. These mechanisms generally provide for timely recovery of market price fluctuations associated with these expenses.

~~Table of Contents~~

Volumetric Risk

Volumetric risk is the risk related to the changes in volume of retail sales due to weather, economic conditions or other factors. PPL is exposed to volumetric risk through its subsidiaries as described below.


•	WPD is exposed to volumetric risk which is significantly mitigated as a result of the method of regulation in the U.K. Under the RIIO-ED1 price control regulations, recovery of such exposure occurs on a two year lag. See Note 1 in PPL's ~~2018~~2019 Form 10-K for additional information on revenue recognition under RIIO-ED1.


•	PPL Electric, LG&E and KU are exposed to volumetric risk on retail sales, mainly due to weather and other economic conditions for which there is limited mitigation between rate cases.

Equity Securities Price Risk

PPL and its subsidiaries are exposed to equity securities price risk associated with the fair value of the defined benefit plans' assets. This risk is significantly mitigated at the regulated domestic utilities and for certain plans at WPD due to the recovery methods in place.

PPL is exposed to equity securities price risk from future stock sales and/or purchases.

Table of Contents

Credit Risk

Credit risk is the potential loss that may be incurred due to a counterparty's non-performance.

PPL is exposed to credit risk from "in-the-money" interest rate and foreign currency derivatives with financial institutions, as well as additional credit risk through certain of its subsidiaries, as discussed below.

In the event a supplier of PPL Electric, LG&E or KU defaults on its obligation, those Registrants would be required to seek replacement power or replacement fuel in the market. In general, subject to regulatory review or other processes, appropriate incremental costs incurred by these entities would be recoverable from customers through applicable rate mechanisms, thereby mitigating the financial risk for these entities.

PPL and its subsidiaries have credit policies in place to manage credit risk, including the use of an established credit approval process, daily monitoring of counterparty positions and the use of master netting agreements or provisions. These agreements generally include credit mitigation provisions, such as margin, prepayment or collateral requirements. PPL and its subsidiaries may request additional credit assurance, in certain circumstances, in the event that the counterparties' credit ratings fall below investment grade, their tangible net worth falls below specified percentages or their exposures exceed an established credit limit.

Master Netting Arrangements (PPL, LKE, LG&E and KU)

Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.

PPL had a ~~$40~~$29 million and $14 million obligation to return cash collateral under master netting arrangements at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018.~~

~~PPL had 0 obligation to post cash collateral under master netting arrangements at September 30, 2019 and December 31, 2018.~~2019.

LKE, LG&E and KU had 0 obligation to return cash collateral under master netting arrangements at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018.~~2019.

PPL, LKE and LG&E posted $1 million of cash collateral under master netting arrangements at March 31, 2020. KU had no obligation to post cash collateral under master netting arrangements at March 31, 2020. PPL, LKE, LG&E and KU had 0 obligation to post cash collateral under master netting arrangements at ~~September 30, 2019 and~~ December 31, ~~2018.~~2019.

See "Offsetting Derivative Instruments" below for a summary of derivative positions presented in the balance sheets where a right of setoff exists under these arrangements.

~~Table of Contents~~

Interest Rate Risk

(All Registrants)

PPL and its subsidiaries issue debt to finance their operations, which exposes them to interest rate risk. A variety of financial derivative instruments are utilized to adjust the mix of fixed and floating interest rates in their debt portfolios, adjust the duration of the debt portfolios and lock in benchmark interest rates in anticipation of future financing, when appropriate. Risk limits under PPL's risk management program are designed to balance risk exposure to volatility in interest expense and changes in the fair value of the debt portfolio due to changes in benchmark interest rates. In addition, the interest rate risk of certain subsidiaries is potentially mitigated as a result of the existing regulatory framework or the timing of rate cases.

Cash Flow Hedges (PPL)

Interest rate risks include exposure to adverse interest rate movements for outstanding variable rate debt and for future anticipated financings. Financial interest rate swap contracts that qualify as cash flow hedges may be entered into to hedge floating interest rate risk associated with both existing and anticipated debt issuances. At March 31, 2020, PPL ~~had no such~~held an aggregate notional value in interest rate swap contracts atof £105 million (approximately $134 million based on spot rates) that mature in 2035 to hedge interest payments of WPD's anticipated September ~~30, 2019.~~2020 debt issuance.

At ~~September 30, 2019,~~March 31, 2020, PPL held an aggregate notional value in cross-currency interest rate swap contracts of $702 million that range in maturity from 2021 through 2028 to hedge the interest payments and principal of WPD's U.S. dollar-denominated senior notes.

Table of Contents

Cash flow hedges are discontinued if it is no longer probable that the original forecasted transaction will occur by the end of the originally specified time period and any amounts previously recorded in AOCI are reclassified into earnings once it is determined that the hedged transaction is not probable of occurring.

For the three ~~and nine~~ months ended ~~September 30,~~March 31, 2020 and 2019, ~~and 2018,~~ PPL had 0 cash flow hedges reclassified into earnings associated with discontinued cash flow hedges.

At ~~September 30, 2019,~~March 31, 2020, the amount of accumulated net unrecognized after-tax gains (losses) on qualifying derivatives expected to be reclassified into earnings during the next 12 months is insignificant. Amounts are reclassified as the hedged interest expense is recorded.

Economic Activity (PPL, LKE and LG&E)

LG&E enters into interest rate swap contracts that economically hedge interest payments on variable rate debt. Because realized gains and losses from the swaps, including terminated swap contracts, are recoverable through regulated rates, any subsequent changes in fair value of these derivatives are included in regulatory assets or liabilities until they are realized as interest expense. Realized gains and losses are recognized in "Interest Expense" on the Statements of Income at the time the underlying hedged interest expense is recorded. At ~~September 30, 2019,~~March 31, 2020, LG&E held contracts with a notional amount of $147 million that range in maturity through 2033.

Foreign Currency Risk (PPL)

PPL is exposed to foreign currency risk, primarily through investments in and earnings of U.K. affiliates. PPL has adopted a foreign currency risk management program designed to hedge certain foreign currency exposures, including firm commitments, recognized assets or liabilities, anticipated transactions and net investments. In addition, PPL enters into financial instruments to protect against foreign currency translation risk of expected GBP earnings.

Net Investment Hedges

PPL enters into foreign currency contracts on behalf of a subsidiary to protect the value of a portion of its net investment in WPD. There were no contracts outstanding at ~~September 30, 2019.~~March 31, 2020.

At ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018,~~2019, PPL had ~~$31~~$32 million of accumulated net investment hedge after tax gains (losses) that were included in the foreign currency translation adjustment component of AOCI.

~~Table of Contents~~

Economic Activity

PPL enters into foreign currency contracts on behalf of a subsidiary to economically hedge GBP-denominated anticipated earnings. At ~~September 30, 2019,~~March 31, 2020, the total exposure hedged by PPL was approximately ~~£1 billion~~£686 million (approximately ~~$1.5~~$1.0 billion based on contracted rates). These contracts have termination dates ranging from ~~October 2019~~April 2020 through ~~December 2020.~~July 2021.

Accounting and Reporting

(All Registrants)

All derivative instruments are recorded at fair value on the Balance Sheet as an asset or liability unless NPNS is elected. NPNS contracts include certain ~~full-requirement~~full requirement purchase contracts and other physical purchase contracts. Changes in the fair value of derivatives not designated as NPNS are recognized in earnings unless specific hedge accounting criteria are met and designated as such, except for the changes in fair values of LG&E's interest rate swaps that are recognized as regulatory assets or regulatory liabilities. See Note 7 for amounts recorded in regulatory assets and regulatory liabilities at ~~September 30, 2019~~March 31, 2020 and December 31, ~~2018.~~2019.

See Note 1 in each Registrant's ~~2018~~2019 Form 10-K for additional information on accounting policies related to derivative instruments.

(PPL)

The following table presents the fair value and location of derivative instruments recorded on the Balance Sheets.

Table of Contents

September 30, 2019 December 31, 2018

Derivatives designated as
hedging instruments

Derivatives not designated
as hedging instruments

Derivatives designated as
hedging instruments

Derivatives not designated
as hedging instruments
Assets Liabilities Assets Liabilities Assets Liabilities Assets Liabilities
Current:

Price Risk Management

Assets/Liabilities (a):

Interest rate swaps (b) $ —
$ —
$ —
$ 5
$ —
$ —
$ —
$ 4
Cross-currency swaps (b) 7
—
—
—
6
—
—
—
Foreign currency contracts —
—
202
3
—
—
103
2
Total current 7
—
202
8
6
—
103
6
Noncurrent:

Price Risk Management

Assets/Liabilities (a):

Interest rate swaps (b) —
—
—
20
—
—
—
16
Cross-currency swaps (b) 188
—
—
—
129
—
—
—
Foreign currency contracts —
—
22
—
—
—
99
—
Total noncurrent 188
—
22
20
129
—
99
16
Total derivatives $ 195
$ —
$ 224
$ 28
$ 135
$ —
$ 202
$ 22



	March 31, 2020								December 31, 2019
	Derivatives designated as hedging instruments				Derivatives not designated as hedging instruments				Derivatives designated as hedging instruments				Derivatives not designated as hedging instruments
	Assets		Liabilities		Assets		Liabilities		Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management
Assets/Liabilities (a):
Interest rate swaps (b)	$	—	$	5	$	—	$	4	$	—	$	—	$	—	$	4
Cross-currency swaps (b)	6		—		—		—		5		—		—		—
Foreign currency contracts	—		—		187		—		—		—		142		5
Total current	6		5		187		4		5		—		142		9
Noncurrent:
Price Risk Management
Assets/Liabilities (a):
Interest rate swaps (b)	—		—		—		25		—		—		—		17
Cross-currency swaps (b)	163		—		—		—		149		—		—		—
Foreign currency contracts	—		—		3		—		—		—		—		—
Total noncurrent	163		—		3		25		149		—		—		17
Total derivatives	$	169	$	5	$	190	$	29	$	154	$	—	$	142	$	26


(a)	Current portion is included in "Price risk management assets" and "Other current liabilities" and noncurrent portion is included in "Price risk management assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets.


(b)	Excludes accrued interest, if applicable.

The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the ~~periods~~period ended ~~September 30, 2019.~~March 31, 2020.



	Three Months				Three Months
Derivative Relationships	Derivative Gain (Loss) Recognized in OCI			Location of Gain (Loss) Recognized in Income on Derivative	Gain (Loss) Reclassified from AOCI into Income
Cash Flow Hedges:
Interest rate swaps	$	(5	)	Interest expense	$	(3	)
Cross-currency swaps	15			Other income (expense) - net	6
Total	$	10			$	3
Net Investment Hedges:
Foreign currency contracts	$	—



Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized in Income on Derivative	Three Months
Foreign currency contracts	Other income (expense) - net	$	62
Interest rate swaps	Interest expense	(1		)
	Total	$	61
Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized as Regulatory Liabilities/Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	(8	)

Table of Contents

Three Months Nine Months Three Months Nine Months
Derivative
Relationships
Derivative Gain
(Loss) Recognized in
OCI
Derivative Gain
(Loss) Recognized in
OCI Location of
Gain (Loss)
Recognized
in Income
on Derivative Gain (Loss)
Reclassified
from AOCI
into Income Gain (Loss)
Reclassified
from AOCI
into
Income
Cash Flow Hedges:
Interest rate swaps $ (22 ) $ (30 ) Interest expense $ (2 ) $ (6 )
Cross-currency swaps 41
69
Other income (expense) - net 27
34
Total $ 19
$ 39
$ 25
$ 28
Net Investment Hedges:

Foreign currency contracts $ —
$ 1

Derivatives Not Designated as Location of Gain (Loss) Recognized in
Hedging Instruments Income on Derivative Three Months Nine Months
Foreign currency contracts Other income (expense) - net $ 44
$ 56
Interest rate swaps Interest expense (1 ) (3 )
Total $ 43
$ 53
Derivatives Not Designated as Location of Gain (Loss) Recognized as
Hedging Instruments Regulatory Liabilities/Assets Three Months Nine Months
Interest rate swaps Regulatory assets - noncurrent $ (2 ) $ (5 )


	Three Months		Nine Months			Three Months			Nine Months			Three Months				Three Months
Derivative Relationships	Derivative Gain (Loss) Recognized in OCI		Derivative Gain (Loss) Recognized in OCI		Location of Gain (Loss) Recognized in Income on Derivative	Gain (Loss) Reclassified from AOCI into Income			Gain (Loss) Reclassified from AOCI into Income			Derivative Gain (Loss) Recognized in OCI			Location of Gain (Loss) Recognized in Income on Derivative	Gain (Loss) Reclassified from AOCI into Income
Cash Flow Hedges:
Interest rate swaps	$	—	$	—	Interest expense	$	(2	)	$	(6	)	$	—		Interest expense	$	(2	)
Cross-currency swaps	27		26		Interest expense	1			1			(23		)	Other income (expense) - net	(28		)
					Other income (expense) - net	18			30
Total	$	27	$	26		$	17		$	25		$	(23	)		$	(30	)
Net Investment Hedges:
Foreign currency contracts	$	—	$	11								$	—

Derivatives Not Designated as Location of Gain (Loss) Recognized in
Hedging Instruments Income on Derivative Three Months Nine Months
Foreign currency contracts Other income (expense) - net $ 40
$ 92
Interest rate swaps Interest expense (1 ) (4 )
Total $ 39
$ 88
Derivatives Not Designated as Location of Gain (Loss) Recognized as
Hedging Instruments Regulatory Liabilities/Assets Three Months Nine Months
Interest rate swaps Regulatory assets - noncurrent $ 2
$ 7



Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized in Income on Derivative	Three Months
Foreign currency contracts	Other income (expense) - net	$	(33	)
Interest rate swaps	Interest expense	(1		)
	Total	$	(34	)
Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized as Regulatory Liabilities/Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	(1	)

The following table presents the effect of cash flow hedge activity on the Statement of Income for the ~~periods end September 30, 2019.~~period ended March 31, 2020.

~~Table of Contents~~

Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships
Three Months Nine Months
Interest Expense Other Income (Expense) - net Interest Expense Other Income (Expense) - net

Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 259
$ 126
$ 746
$ 309
The effects of cash flow hedges:
Gain (Loss) on cash flow hedging relationships:
Interest rate swaps:
Amount of gain (loss) reclassified from AOCI to income (2 ) —
(6 ) —
Cross-currency swaps:
Hedged items —
(27 ) —
(34 )
Amount of gain (loss) reclassified from AOCI to income —
27
—
34



	Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships
	Three Months
	Interest Expense			Other Income (Expense) - net
	Interest Expense			Other Income (Expense) - net
Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded	$	248		$	125
The effects of cash flow hedges:
Gain (Loss) on cash flow hedging relationships:
Interest rate swaps:
Amount of gain (loss) reclassified from AOCI to income	(3		)	—
Cross-currency swaps:
Hedged items	—			(6		)
Amount of gain (loss) reclassified from AOCI to income	—			6

(LKE and LG&E)

The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments.


	September 30, 2019				December 31, 2018				March 31, 2020				December 31, 2019
	Assets		Liabilities		Assets		Liabilities		Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	$	—	$	5	$	—	$	4	$	—	$	4	$	—	$	4
Total current	—		5		—		4		—		4		—		4
Noncurrent:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	—		20		—		16
Total noncurrent	—		20		—		16
Total derivatives	$	—	$	25	$	—	$	20

Table of Contents



	March 31, 2020				December 31, 2019
	Assets		Liabilities		Assets		Liabilities
Noncurrent:
Price Risk Management
Assets/Liabilities:
Interest rate swaps	—		25		—		17
Total noncurrent	—		25		—		17
Total derivatives	$	—	$	29	$	—	$	21

The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the ~~periods~~period ended ~~September 30, 2019.~~March 31, 2020.


	Location of Gain (Loss) Recognized in							Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Nine Months			Income on Derivatives	Three Months
Interest rate swaps	Interest expense	$	(1	)	$	(3	)	Interest expense	$	(1	)
	Location of Gain (Loss) Recognized in							Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Nine Months			Regulatory Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	(2	)	$	(5	)	Regulatory assets - noncurrent	$	(8	)


	Location of Gain (Loss) Recognized in							Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months			Nine Months			Income on Derivatives	Three Months
Interest rate swaps	Interest expense	$	(1	)	$	(4	)	Interest expense	$	(1	)
	Location of Gain (Loss) Recognized in							Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months			Nine Months			Regulatory Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	2		$	7		Regulatory assets - noncurrent	$	(1	)

~~Table of Contents~~

(PPL, LKE, LG&E and KU)

Offsetting Derivative Instruments

PPL, LKE, LG&E and KU or certain of their subsidiaries have master netting arrangements in place and also enter into agreements pursuant to which they purchase or sell certain energy and other products. Under the agreements, upon termination of the agreement as a result of a default or other termination event, the non-defaulting party typically would have a right to set off amounts owed under the agreement against any other obligations arising between the two parties (whether under the agreement or not), whether matured or contingent and irrespective of the currency, place of payment or place of booking of the obligation.

PPL, LKE, LG&E and KU have elected not to offset derivative assets and liabilities and not to offset net derivative positions against the right to reclaim cash collateral pledged (an asset) or the obligation to return cash collateral received (a liability) under derivatives agreements. The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.


	Assets								Liabilities								Assets								Liabilities
			Eligible for Offset								Eligible for Offset								Eligible for Offset								Eligible for Offset
	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net		Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
September 30, 2019
March 31, 2020
Treasury Derivatives
PPL	$	419	$	3	$	40	$	376	$	28	$	3	$	—	$	25	$	359	$	—	$	29	$	330	$	34	$	—	$	1	$	33
LKE	—		—		—		—		25		—		—		25		—		—		—		—		29		—		1		28
LG&E	—		—		—		—		25		—		—		25		—		—		—		—		29		—		1		28

Assets Liabilities
Eligible for Offset Eligible for Offset
Gross
Derivative
Instruments

Cash
Collateral
Received
Net Gross
Derivative
Instruments

Cash
Collateral
Pledged
Net
December 31, 2018
Treasury Derivatives
PPL $ 337
$ 2
$ 40
$ 295
$ 22
$ 2
$ —
$ 20
LKE —
—
—
—
20
—
—
20
LG&E —
—
—
—
20
—
—
20

Table of Contents



	Assets								Liabilities
			Eligible for Offset								Eligible for Offset
	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
December 31, 2019
Treasury Derivatives
PPL	$	296	$	5	$	14	$	277	$	26	$	5	$	—	$	21
LKE	—		—		—		—		21		—		—		21
LG&E	—		—		—		—		21		—		—		21

Credit Risk-Related Contingent Features

Certain derivative contracts contain credit risk-related contingent features which, when in a net liability position, would permit the counterparties to require the transfer of additional collateral upon a decrease in the credit ratings of PPL, LKE, LG&E and KU or certain of their subsidiaries. Most of these features would require the transfer of additional collateral or permit the counterparty to terminate the contract if the applicable credit rating were to fall below investment grade. Some of these features also would allow the counterparty to require additional collateral upon each downgrade in credit rating at levels that remain above investment grade. In either case, if the applicable credit rating were to fall below investment grade, and assuming no assignment to an investment grade affiliate were allowed, most of these credit contingent features require either immediate payment of the net liability as a termination payment or immediate and ongoing full collateralization on derivative instruments in net liability positions.

Additionally, certain derivative contracts contain credit risk-related contingent features that require adequate assurance of performance be provided if the other party has reasonable concerns regarding the performance of PPL's, LKE's, LG&E's and KU's obligations under the contracts. A counterparty demanding adequate assurance could require a transfer of additional collateral or other security, including letters of credit, cash and guarantees from a creditworthy entity. This would typically involve negotiations among the parties. However, amounts disclosed below represent assumed immediate payment or immediate and ongoing full collateralization for derivative instruments in net liability positions with "adequate assurance" features.

~~Table of Contents~~

(PPL, LKE and LG&E)

At ~~September 30, 2019,~~March 31, 2020, derivative contracts in a net liability position that contain credit risk-related contingent features, collateral posted on those positions and the related effect of a decrease in credit ratings below investment grade are summarized as follows:


	PPL		LKE		LG&E		PPL		LKE		LG&E
Aggregate fair value of derivative instruments in a net liability position with credit risk-related contingent features	$	4	$	4	$	4	$	6	$	2	$	2
Aggregate fair value of collateral posted on these derivative instruments	—		—		—		—		—		—
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade (a)	4		4		4		6		2		2


(a)	Includes the effect of net receivables and payables already recorded on the Balance Sheet.

~~16.~~15. Asset Retirement Obligations

(PPL, LKE, LG&E and KU)

PPL's, LKE's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 1110 for information on the CCR rule. LG&E also has AROs related to natural gas mains and wells. LG&E's and KU's transmission and distribution lines largely operate under perpetual property easement agreements, which do not generally require restoration upon removal of the property. Therefore, no material AROs are recorded for transmission and distribution assets. For LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability.

Table of Contents

The changes in the carrying amounts of AROs were as follows.


	PPL			LKE			LG&E			KU			PPL			LKE			LG&E			KU
Balance at December 31, 2018	$	347		$	296		$	103		$	193
Balance at December 31, 2019													$	282		$	215		$	73		$	142
Accretion	13			12			4			8			4			4			1			3
Effect of foreign exchange rates	(2		)	—			—			—
Changes in estimated timing or cost	(5		)	(2		)	(2		)	—			18			18			—			18
Obligations settled	(67		)	(67		)	(22		)	(45		)	(20		)	(20		)	(7		)	(13		)
Balance at September 30, 2019	$	286		$	239		$	83		$	156
Balance at March 31, 2020													$	284		$	217		$	67		$	150

~~17.~~16. Accumulated Other Comprehensive Income (Loss)

(PPL)

The after-tax changes in AOCI by component for the periods ended ~~September 30~~March 31 were as follows.

Foreign
currency
translation
adjustments

Unrealized gains (losses)
on qualifying
derivatives
Defined benefit plans

Prior
service
costs

Actuarial
gain
(loss)
Total
PPL
June 30, 2019 $ (1,616 ) $ 6
$ (18 ) $ (2,368 ) $ (3,996 )
Amounts arising during the period (285 ) 16
—
(5 ) (274 )
Reclassifications from AOCI —
(22 ) —
20
(2 )
Net OCI during the period (285 ) (6 ) —
15
(276 )
September 30, 2019 $ (1,901 ) $ —
$ (18 ) $ (2,353 ) $ (4,272 )

~~Table of Contents~~


	Foreign currency translation adjustments			Unrealized gains (losses) on qualifying derivatives				Defined benefit plans											Foreign currency translation adjustments				Unrealized gains (losses) on qualifying derivatives			Defined benefit plans
	Foreign currency translation adjustments						Prior service costs				Actuarial gain (loss)				Total							Prior service costs				Actuarial gain (loss)			Total
PPL																			Foreign currency translation adjustments				Unrealized gains (losses) on qualifying derivatives
December 31, 2019																			$	(1,425	)		$	(5	)	$	(18	)	$	(2,910	)	$	(4,358	)
Amounts arising during the period																			(61		)		8			—			—			(53		)
Reclassifications from AOCI																			—				(3		)	1			47			45
Net OCI during the period																			(61		)		5			1			47			(8		)
March 31, 2020																			$	(1,486	)		$	—		$	(17	)	$	(2,863	)	$	(4,366	)
				Unrealized gains (losses) on qualifying derivatives
December 31, 2018	$	(1,533	)	$	(7	)		$	(19	)		$	(2,405	)		$	(3,964	)	$	(1,533	)		$	(7	)	$	(19	)	$	(2,405	)	$	(3,964	)
Amounts arising during the period	(368		)	32				—				(10		)		(346		)	294				(19		)	—			(3		)	272
Reclassifications from AOCI	—			(25		)		1				62				38			—				24			—			21			45
Net OCI during the period	(368		)	7				1				52				(308		)	294				5			—			18			317
September 30, 2019	$	(1,901	)	$	—			$	(18	)		$	(2,353	)		$	(4,272	)

June 30, 2018	$	(1,223	)	$	(21	)		$	(7	)		$	(2,244	)		$	(3,495	)
Amounts arising during the period	(187		)	22				—				(8		)		(173		)
Reclassifications from AOCI	—			(14		)		—				34				20
Net OCI during the period	(187		)	8				—				26				(153		)
September 30, 2018	$	(1,410	)	$	(13	)		$	(7	)		$	(2,218	)		$	(3,648	)

December 31, 2017	$	(1,089	)	$	(13	)		$	(7	)		$	(2,313	)		$	(3,422	)
Amounts arising during the period	(321		)	21				(1		)		(9		)		(310		)
Reclassifications from AOCI	—			(21		)		1				104				84
Net OCI during the period	(321		)	—				—				95				(226		)
September 30, 2018	$	(1,410	)	$	(13	)		$	(7	)		$	(2,218	)		$	(3,648	)
March 31, 2019																			$	(1,239	)		$	(2	)	$	(19	)	$	(2,387	)	$	(3,647	)

The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the periods ended ~~September 30.~~March 31.


	Three Months						Nine Months						Affected Line Item on the	Three Months						Affected Line Item on the
Details about AOCI	2019			2018			2019			2018			Statements of Income	2020			2019			Statements of Income
Qualifying derivatives
Interest rate swaps	$	(2	)	$	(2	)	$	(6	)	$	(6	)	Interest Expense	$	(3	)	$	(2	)	Interest Expense
Cross-currency swaps	27			18			34			30			Other Income (Expense) - net	6			(28		)	Other Income (Expense) - net
	—			1			—			1			Interest Expense
Total Pre-tax	25			17			28			25				3			(30		)
Income Taxes	(3		)	(3		)	(3		)	(4		)		—			6
Total After-tax	22			14			25			21				3			(24		)

Defined benefit plans
Prior service costs (a)	(1		)	(1		)	(2		)	(2		)		(1		)	—
Net actuarial loss (a)	(25		)	(42		)	(78		)	(130		)		(59		)	(26		)
Total Pre-tax	(26		)	(43		)	(80		)	(132		)		(60		)	(26		)
Income Taxes	6			9			17			27				12			5
Total After-tax	(20		)	(34		)	(63		)	(105		)		(48		)	(21		)

Total reclassifications during the period	$	2		$	(20	)	$	(38	)	$	(84	)		$	(45	)	$	(45	)


(a)	These AOCI components are included in the computation of net periodic defined benefit cost. See Note 109 for additional information.

~~18. New Accounting Guidance Pending Adoption~~

~~(All Registrants)~~

~~Accounting for Financial Instrument Credit Losses~~

In June 2016, the FASB issued accounting guidance that requires the use of a current expected credit loss (CECL) model for the measurement of credit losses on financial instruments within the scope of this guidance, which includes accounts receivable. The CECL model requires an entity to measure credit losses using historical information, current information and reasonable and supportable forecasts of future events, rather than the incurred loss impairment model required under current GAAP.

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For public business entities, this guidance will be applied using a modified retrospective approach and is effective for fiscal years beginning after December 15, 2019, and interim periods within those years. The Registrants are currently assessing the impact of adopting this guidance and will adopt this standard on January 1, 2020 with a modified retrospective approach through a cumulative-effect adjustment to retained earnings at the date of adoption. Key implementation activities in process include finalizing the population of financial instruments within the scope of this guidance and identifying potential differences between the Registrants’ current credit loss models and the requirements of this guidance.

~~Accounting for Implementation Costs in a Cloud Computing Service Arrangement~~

In August 2018, the FASB issued accounting guidance that requires a customer in a cloud computing hosting arrangement that is a service contract to capitalize implementation costs consistent with internal-use software guidance for non-service arrangements. Prior guidance had not addressed these implementation costs. The guidance requires these capitalized implementation costs to be amortized over the term of the hosting arrangement to the statement of income line item where the service arrangement costs are recorded. The guidance also prescribes the financial statement classification of the capitalized implementation costs and cash flows associated with the arrangement. Additional quantitative and qualitative disclosures are also required.

For public business entities, this guidance is effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2019. This standard must be applied either retrospectively or prospectively to all implementation costs incurred after the date of adoption.

The Registrants are currently assessing the impact of adopting this guidance and will adopt this standard prospectively as of the beginning of the period adopted, which will be January 1, 2020. Key implementation activities in process of being completed include assessing the population of cloud computing hosting arrangements in the scope of this guidance and identifying and evaluating industry issues.

~~(PPL, LKE, LG&E and KU)~~

~~Simplifying the Test for Goodwill Impairment~~

In January 2017, the FASB issued accounting guidance that simplifies the test for goodwill impairment by eliminating the second step of the quantitative test. The second step of the quantitative test requires a calculation of the implied fair value of goodwill, which is determined in the same manner as the amount of goodwill in a business combination. Under this new guidance, an entity will now compare the estimated fair value of a reporting unit with its carrying value and recognize an impairment charge for the amount the carrying amount exceeds the fair value of the reporting unit.

For public business entities, this guidance will be applied prospectively and is effective for annual or any interim goodwill impairment tests for fiscal years beginning after December 15, 2019. The Registrants will adopt this guidance on January 1, 2020. The Registrants are currently assessing the impact of adopting this guidance.

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Item 2. Combined Management's Discussion and Analysis of Financial Condition and

Results of Operations

(All Registrants)

This "Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" is separately filed by PPL, PPL Electric, LKE, LG&E and KU. Information contained herein relating to any individual Registrant is filed by such Registrant solely on its own behalf, and no Registrant makes any representation as to information relating to any other Registrant. The specific Registrant to which disclosures are applicable is identified in parenthetical headings in italics above the applicable disclosure or within the applicable disclosure for each Registrant's related activities and disclosures. Within combined disclosures, amounts are disclosed for individual Registrants when significant.

The following should be read in conjunction with the Registrants' Condensed Consolidated Financial Statements and the accompanying Notes and with the Registrants' ~~2018~~2019 Form 10-K. Capitalized terms and abbreviations are defined in the glossary. Dollars are in millions, except per share data, unless otherwise noted.

"Management's Discussion and Analysis of Financial Condition and Results of Operations" includes the following information:

"Overview" provides a description of each Registrant's business strategy and a discussion of important financial and operational developments.

"Results of Operations" for all Registrants includes a "Statement of Income ~~Analysis"~~Analysis," which discusses significant changes in principal line items on the Statements of Income, comparing the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 with the same ~~periods~~period in ~~2018.~~2019. For PPL, "Results of Operations" also includes "Segment Earnings" and "Adjusted Gross ~~Margins"~~Margins," which provide a detailed analysis of earnings by reportable segment. These discussions include non-GAAP financial measures, including "Earnings from Ongoing Operations" and "Adjusted Gross Margins" and provide explanations of the non-GAAP financial measures and a reconciliation of the non-GAAP financial measures to the most comparable GAAP measure. ~~For PPL Electric, LKE, LG&E and KU, a summary of Earnings and Adjusted Gross Margins is also provided.~~

"Financial Condition - Liquidity and Capital Resources" provides an analysis of the Registrants' liquidity positions and credit profiles. This section also includes a discussion of rating agency actions.

"Financial Condition - Risk Management" provides an explanation of the Registrants' risk management programs relating to market and credit risk.

Overview

Introduction

(PPL)

PPL, headquartered in Allentown, Pennsylvania, is a utility holding company. PPL, through its regulated utility subsidiaries, delivers electricity to customers in the U.K., Pennsylvania, Kentucky and Virginia; delivers natural gas to customers in Kentucky; and generates electricity from power plants in Kentucky.

PPL's principal subsidiaries are shown below (* denotes a Registrant).

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PPL Corporation*

PPL Capital Funding

Provides financing for the operations of PPL and certain subsidiaries

PPL Global

Engages in the regulated distribution of electricity in the U.K.

LKE*

PPL Electric*

Engages in the regulated transmission and distribution of electricity in Pennsylvania

LG&E*

Engages in the regulated generation, transmission, distribution and sale of electricity and regulated distribution and sale of natural gas in Kentucky

KU*

Engages in the regulated generation, transmission, distribution and sale of electricity, primarily in Kentucky

U.K.

Regulated Segment

Kentucky

Regulated Segment

Pennsylvania

Regulated Segment

PPL's reportable segments' results primarily represent the results of PPL Global, LKE and PPL Electric, except that the reportable segments are also allocated certain corporate level financing and other costs that are not included in the results of PPL Global, LKE and PPL Electric. PPL Global is not a Registrant. Unaudited annual consolidated financial statements for the U.K. Regulated segment are furnished on a Form 8-K with the SEC.

In addition to PPL, the other Registrants included in this filing are as follows.

(PPL Electric)

PPL Electric, headquartered in Allentown, Pennsylvania, is a wholly owned subsidiary of PPL and a regulated public utility that is an electricity transmission and distribution service provider in eastern and central Pennsylvania. PPL Electric is subject to regulation as a public utility by the PUC, and certain of its transmission activities are subject to the jurisdiction of the FERC under the Federal Power Act. PPL Electric delivers electricity in its Pennsylvania service area and provides electricity supply to retail customers in that area as a PLR under the Customer Choice Act.

(LKE)

LKE, acquired in 2010 and headquartered in Louisville, Kentucky, is a wholly owned subsidiary of PPL and a holding company that owns regulated utility operations through its subsidiaries, LG&E and KU, which constitute substantially all of LKE's assets. LG&E and KU are engaged in the generation, transmission, distribution and sale of electricity. LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain separate corporate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia under the Old Dominion Power name.

(LG&E)

LG&E, headquartered in Louisville, Kentucky, is a wholly owned subsidiary of LKE and a regulated utility engaged in the generation, transmission, distribution and sale of electricity and distribution and sale of natural gas in Kentucky. LG&E is subject to regulation as a public utility by the KPSC, and certain of its transmission activities are subject to the jurisdiction of the FERC under the Federal Power Act.

(KU)

KU, headquartered in Lexington, Kentucky, is a wholly owned subsidiary of LKE and a regulated utility engaged in the generation, transmission, distribution and sale of electricity in Kentucky and Virginia. KU is subject to regulation as a public

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utility by the KPSC, the VSCC and certain of its transmission and wholesale power activities are subject to the jurisdiction of the FERC under the Federal Power Act. KU serves its Kentucky customers under the KU name and its Virginia customers under the Old Dominion Power name.

Business Strategy

(All Registrants)

PPL operates seven fully regulated, high-performing utilities. These utilities are located in the U.K., Pennsylvania and Kentucky, in constructive regulatory jurisdictions with distinct regulatory structures and customer classes. PPL believes this business portfolio positions the company well for continued success and provides earnings and dividend growth potential.

PPL's strategy, and that of the other Registrants, is to deliver best-in-sector operational performance, invest in a sustainable energy future, maintain a strong financial foundation, and engage and develop its people. PPL's business plan is designed to achieve growth by providing efficient, reliable and safe operations and strong customer service, maintaining constructive regulatory relationships and achieving timely recovery of costs. These businesses are expected to achieve strong, long-term growth in rate base in the U.S. and RAV in the U.K. Rate base growth is being driven by planned significant capital expenditures to maintain existing assets and improve system reliability and, for LKE, LG&E and KU, to comply with federal and state environmental regulations related to coal-fired electricity generation facilities.

For the U.S. businesses, central to PPL's strategy is recovering capital project costs efficiently through various rate-making mechanisms, including periodic base rate case proceedings using forward test years, annual FERC formula rate mechanisms and other regulatory agency-approved recovery mechanisms designed to limit regulatory lag. In Kentucky, the KPSC has adopted a series of regulatory mechanisms (ECR, DSM, GLT, fuel adjustment clause, and gas supply clause) and recovery on construction work-in-progress that reduce regulatory lag and provide timely recovery of and return on, as appropriate, prudently incurred costs. In addition, the KPSC requires a utility to obtain a CPCN prior to constructing a facility, unless the construction is an ordinary extension of existing facilities in the usual course of business or does not involve sufficient capital expenditures to materially affect the utility's financial condition. Although such KPSC proceedings do not directly address cost recovery issues, the KPSC, in awarding a CPCN, concludes that the public convenience and necessity require the construction of the facility on the basis that the facility is the lowest reasonable cost alternative to address the need. In Pennsylvania, the FERC transmission formula rate, DSIC mechanism, Smart Meter Rider and other recovery mechanisms operate to reduce regulatory lag and provide for timely recovery of and a return on, as appropriate, prudently incurred costs.

To manage financing costs and access to credit markets, and to fund capital expenditures, a key objective of the Registrants is to maintain their investment grade credit ratings and adequate liquidity positions. In addition, the Registrants have financial and operational risk management programs that, among other things, are designed to monitor and manage exposure to earnings and cash flow volatility, as applicable, related to changes in interest rates, foreign currency exchange rates and counterparty credit quality. To manage these risks, PPL generally uses contracts such as forwards, options and swaps. See "Financial Condition - Risk Management" below for further information.

Earnings generated by PPL's U.K. subsidiaries are subject to foreign currency translation risk. Because WPD's earnings represent such a significant portion of PPL's consolidated earnings, PPL enters into foreign currency contracts to economically hedge the value of the GBP versus the U.S. dollar. These hedges do not receive hedge accounting treatment under GAAP. See "Financial and Operational Developments - U.K. Membership in European Union" for additional discussion of the U.K. earnings hedging activity.

The U.K. subsidiaries also have currency exposure to the U.S. dollar to the extent of their U.S. dollar denominated debt. To manage these risks, PPL generally uses contracts such as forwards, options and cross-currency swaps that contain characteristics of both interest rate and foreign currency exchange contracts.

As discussed above, a key component of this strategy is to maintain constructive relationships with regulators in all jurisdictions in which the Registrants operate (U.K., U.S. federal and state). This is supported by a strong culture of integrity and delivering on commitments to customers, regulators and shareowners, and a commitment to continue to improve customer service, reliability and operational efficiency.

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Financial and Operational Developments

Outbreak of COVID-19(All Registrants)

In recent weeks, the continued spread of COVID-19 has led to global economic disruption and volatility in financial markets. The Registrants have taken significant steps to mitigate the potential spread of COVID-19 to our customers, suppliers and employees. PPL has successfully implemented its company-wide pandemic plan, which guides the emergency response. Business continuity and other precautionary measures have been taken to ensure we can continue to safely provide reliable electricity and gas service to our customers. The Registrants have implemented social distancing measures for all employees including work from home arrangements where possible and continue to implement strong physical and cyber security measures to ensure that systems function effectively to serve operational and remote workforce needs. The Registrants continue to monitor developments affecting their workforces and customers and will take additional actions as appropriate to respond to changing conditions and mitigate the impacts.

This is a rapidly evolving situation that could lead to extended disruption of economic activity in the Registrants’ markets for an undetermined period of time. Lock-down or closure of non-essential businesses has occurred in each of the Registrants’ service territories, which has resulted in reductions in commercial and industrial demand and an increase in residential demand for electricity service. The financial impact of this net reduction in load was not material to the first quarter financial results. The impact on future periods will depend upon various factors, including the pace and extent to which the Registrants' jurisdictions reopen their economies and community response to the reopening of businesses as well as the extent that businesses continue work from home protocols. We cannot predict these factors and therefore cannot quantify the overall impact COVID-19 will have on our 2020 results of operations.

The Registrants are committed to supporting their customers and communities and have followed federal and state mandates to suspend disconnections for non-payment and new late fees and have worked to reconnect service for customers who had previously been disconnected, where required. Despite suspension of disconnections for non-payment, the Registrants have not experienced a significant reduction of cash receipts and have not adjusted their allowance for uncollectible accounts for potential additional expected credit losses. The Registrants will continue to monitor cash receipts to determine if future increases in their allowance for uncollectible accounts is required.

At March 31, 2020, the Registrants had approximately $3.1 billion of combined unused credit facility capacity. In addition, PPL Capital Funding, PPL Electric, LG&E and KU may, subject to certain conditions, increase their syndicated credit facilities in an aggregate amount of up to $1 billion. In addition, in early April 2020, PPL Capital Funding borrowed an additional $200 million aggregate amount under one and two-year term loan credit facilities and issued $1 billion in senior notes. Based on these actions the Registrants do not anticipate a significant impact on their financial condition or liquidity, and do not foresee difficulties in accessing the capital markets in the near-term. See Note 8 to the Financial Statements for additional information.

The Registrants have assessed the fair value of their assets and liabilities and no impairment charges were required. See “Goodwill Assessment” below for additional information on the interim goodwill impairment test performed for the U.K. Regulated segment reporting unit in the first quarter of 2020.

PPL’s pension plans continue to be well-funded as its liability-driven investment strategy and active management have mitigated investment losses resulting from recent market volatility and significant declines in equity values.

PPL has executed hedges to mitigate the foreign exchange risk to its U.K. earnings. The COVID-19 outbreak has put additional downward pressure on the GBP to U.S. dollar exchange rate. As of March 31, 2020, PPL's foreign exchange exposure related to budgeted earnings is approximately 86% hedged for 2020 at an average rate of $1.55 per GBP and approximately 8% hedged for 2021 at an average rate of $1.32 per GBP. Although PPL cannot predict the impact of COVID-19 on foreign exchange rates, the impact could be significant.

In response to COVID-19, on March 27, 2020, President Donald Trump signed into law the Coronavirus Aid, Relief, and Economic Security Act (the CARES Act). PPL evaluated the provisions of the CARES Act as of March 31, 2020 and believes there is no significant effect on its financial statements. Certain tax provisions may result in immaterial cash benefits in 2020.

To date, there has been no material impact on the Registrants’ business, results of operations, financial condition, liquidity or on their supply chain as a result of COVID-19; however, the ultimate severity or duration of the outbreak or its effects on the global economy, the capital markets, or the Registrants’ workforce, contractors, customers and suppliers is uncertain. The

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Registrants cannot predict the ultimate impact COVID-19 will have on their financial position, results of operations, cash flows or liquidity.

Goodwill Assessment (PPL, LKE, LG&E and KU)

PPL, LKE, LG&E and KU considered whether these events would more likely than not reduce the fair value of the Registrants’ reporting units below their carrying amounts.Based on our assessment, a quantitative impairment test was not required for the LKE, LG&E and KU reporting units, but was required for the U.K. Regulated segment reporting unit, the allocated goodwill of which was $2.5 billion at March 31, 2020.The test did not indicate impairment of the reporting unit.

Management used both discounted cash flows and market multiples, including implied RAV premiums, which required significant assumptions, to estimate the fair value of the reporting units. Significant assumptions used in the discounted cash flows include discount and growth rates, the finalization of RIIO-ED2, and projected operating and capital cash flows. Projected operating and capital cash flows are based on the internal business plans, which assume the occurrence of certain future events. Significant assumptions used in the market multiples include sector market performance and comparable transactions.

A high degree of judgment is required to develop estimates related to fair value conclusions. A decrease in the forecasted cash flows of 10%, an increase in the discount rate of 10%, or a 10% decrease in the market multiples would not have resulted in an impairment of goodwill for the U.K. Regulated segment reporting unit.

U.K. Corporation Tax Rate Change (PPL)

The U.K. corporation tax rate was scheduled to reduce from 19% to 17%, effective April 1, 2020. On March 11, 2020, the U.K. Spring Budget 2020 was announced and included a cancellation of the tax rate reduction to 17%. Maintaining the corporation tax rate at 19% for financial years 2020 and 2021 is expected to be included in the Finance Act 2020, which PPL expects will be approved and enacted into law in the third quarter of 2020. The impact of the cancellation of the corporate tax rate reduction, if enacted as proposed, would be an increase in deferred tax liabilities and a corresponding deferred tax cost of approximately $100 to $110 million.

U.S. Tax Reform (All Registrants)

U.K. Membership in European Union (PPL)

~~Following a June 2016 voter referendum, on~~In March ~~29,~~ 2017, the U.K. Government invoked Article 50 (Article 50) of the Lisbon Treaty, formally beginning the two-year period ~~provided by Article 50~~ for the U.K. to negotiate an agreement specifying the terms of its withdrawal from the European Union (EU), popularly referred to as Brexit. Any withdrawal agreement is subject to approval by the parliaments of both the U.K. and EU. In the absence of a withdrawal agreement, unless an extension of the two-year Article 50 time period were granted or the U.K. were to rescind its Article 50 notification, the U.K.’s membershipAfter repeated extensions, in ~~the EU would originally have terminated on March 29, 2019. On April 10, 2019, the U.K. requested an extension of the Article 50 process and the EU approved an extension until~~ October ~~31, 2019. On October 28,~~ 2019, the EU agreed to extend the Article 50 process until January

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31, 2020. ~~The U.K. Parliament subsequently approved~~Following an early general election ~~for~~in December ~~12, 2019.~~2019, which resulted in a substantial Conservative Party Parliamentary majority, the U.K. and EU Parliaments voted to approve the EU withdrawal agreement negotiated by Prime Minister Boris Johnson.

The U.K. formally left the EU on January 31, 2020, entering a transition period that is scheduled to end on December 31, 2020. During the transition period, the U.K. will seek to negotiate a free trade arrangement with the EU and also negotiate new trade terms with countries outside of the EU. Significant uncertainty continues to surround the outcome of the ~~Brexit process.~~transition period. PPL believes that its greatest ~~risk related~~risks relate to ~~Brexit is an~~any extended period of depressed value of the GBP or the potential further decline in the value of the GBP compared to the U.S. ~~dollar, particularly if the U.K. leaves the EU without a withdrawal agreement.~~dollar. A decline in the value of the GBP compared to the U.S. dollar will reduce the value of WPD's earnings to PPL.

PPL has executed hedges to mitigate the foreign exchange risk to its U.K. earnings. As of ~~September 30, 2019,~~March 31, 2020, PPL's foreign exchange exposure related to budgeted earnings is ~~100% hedged for the remainder of 2019 at an average rate of $1.45 per GBP and 70%~~approximately 86% hedged for 2020 at an average rate of ~~$1.46~~$1.55 per GBP and approximately 8% hedged for 2021 at an average rate of $1.32 per GBP.

PPL cannot predict the impact, in either the short-term or long-term, on foreign exchange rates or PPL's financial condition that may be experienced as a result of the actions taken by the U.K. government to withdraw from the EU, although such impacts could be material.

PPL does not expect the financial condition and results of operations of WPD, itself, to change significantly as a result of Brexit. The regulatory environment and operation of WPD's businesses are not expected to change. RIIO-ED1, the current price control, with allowed revenues agreed with Ofgem runs through March 2023. The impact of a slower economy or recession on WPD would be mitigated in part because U.K. regulation provides that any reduction in the volume of electricity delivered will be recovered in allowed revenues in future periods through the K-factor adjustment. See "Item 1. Business - Segment Information - U.K. Regulated Segment" in PPL's ~~2018~~2019 Form 10-K for additional information on the current price control and K-factor adjustment. In addition, an increase in inflation would have a positive effect on revenues and RAV as annual inflation adjustments are applied to both revenues and RAV (and real returns are earned on inflated RAV). This impact, however, would be partially offset by higher operation and maintenance expenses and interest expense on index-linked debt. With respect to access to financing, WPD has substantial borrowing capacity under existing credit facilities and expects to continue to have access to all major financial markets. With respect to access to and cost of equipment and other materials, WPD management continues to review U.K. government issued advice on preparations for Brexit ~~without an approved plan of withdrawal~~ and has taken actions to mitigate potential increasing costs and disruption to its critical sources of supply. Additionally, less than 1% of WPD's employees are non-U.K. EU nationals and no change in their domicile is expected.

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Regulatory Requirements

(All Registrants)

The Registrants cannot predict the impact that future regulatory requirements may have on their financial condition or results of operations.

(PPL, LKE, LG&E and KU)

The businesses of LKE, LG&E and KU are subject to extensive federal, state and local environmental laws, rules and regulations, including those pertaining to CCRs, GHG, and ELGs. See Notes 7, 1110 and 1615 to the Financial Statements for a discussion of these significant environmental matters. These and other stringent environmental requirements led PPL, LKE, LG&E and KU to retire approximately 1,000 MW of coal-fired generating plants in Kentucky since 2015.

~~TCJA Impact on FERC Rates (All Registrants)~~

~~Pennsylvania Alternative Ratemaking (PPL and PPL Electric)~~

In June 2018, Governor Tom Wolf signed into law Act 58 of 2018 (codified at 66 Pa. C.S. § 1330) authorizing public utilities to implement alternative rates and rate mechanisms in base rate proceedings before the PUC. The effective date of Act 58 was August 27, 2018. Under the new law, a public utility may file an application to establish alternative rates and rate mechanisms in a base rate proceeding. These alternative rates and rate mechanisms include, but are not limited to, decoupling mechanisms, performance-based rates, formula rates, multi-year rate plans, or a combination of those or other mechanisms.

On April 25, 2019, the PUC issued an Implementation Order adopting its interpretation and implementation of Act 58 and establishing the procedures through which utilities may seek PUC approval of alternative rates and rate mechanisms.

~~RIIO-ED2 Review~~RIIO-2 Framework (PPL)

In 2018, Ofgem ~~published~~issued its ~~decision~~consultation document on the ~~overall~~ RIIO-2 framework, ~~which covers~~covering all U.K. gas and electricity transmission and distribution price ~~controls,~~controls. The current electricity distribution price control, RIIO-ED1, continues through March 31, 2023 and will not be impacted by the RIIO-2 consultation process. Later in 2018, Ofgem published its decision following its RIIO-2 framework consultation ~~process earlier in the year. See “Item 7. Combined Management's Discussion~~after consideration of comments received including those from WPD and Analysis of Financial Condition and Results of Operations - Overview - Financial and Operational Developments - Regulatory Requirements - RIIO-2 Framework Review,” in PPL's 2018 Form 10-K for details about the decision document. Management expects significant electricity distribution network investment will be required in RIIO-ED2 to achieve the U.K.’s carbon reduction targets and that Ofgem will need to design a framework that sufficiently incentivizes delivery of those objectives.PPL.

In August 2019, Ofgem published an open letter seeking views on its proposed sector specific approach on the RIIO-ED2 framework. WPD and PPL provided responses to this open letter. In December 2019, Ofgem published its decision on the RIIO-ED2 framework, thus confirming the following points in its RIIO-2 and RIIO-ED2 framework decision documents:

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~~On August 6, 2019,~~

RIIO-ED2 will be a five-year price control period, compared to eight years in the current RIIO-ED1 price control.

CPI or CPIH will be used for inflation measurement in calculating both RAV and allowed returns rather than RPI.

The baseline allowed return on equity will be set using the same methodology in all RIIO-2 sectors. The new methodology includes; (a) an equity indexation, whereby the allowed return on equity is updated to reflect changes in the risk-free rate, and (b) potentially setting the allowed return 0.5% below the expected return.

Full debt indexation will be retained.

The early settlement process (fast tracking) will be removed and replaced with an alternative mechanism to incentivize high-quality, rigorous and ambitious business plans.

The Totex incentive rate will be based on a confidence level for setting baseline cost allowances.

A new enhanced engagement model will be introduced requiring distribution companies to set up a customer engagement group to provide Ofgem ~~published its open letter consultation officially commencing~~with a public report of local stakeholders’ views on the companies’ business plans. Ofgem will also establish an independent RIIO-2 challenge group comprised of consumer experts to provide Ofgem with a public report on companies’ business plans.

There will be no change to the existing depreciation policy of using economic asset lives as the basis for depreciating RAV as part of base revenue calculations. WPD is currently transitioning to 45-year asset lives for new additions in RIIO-ED1 based on Ofgem’s extensive review of asset lives in RIIO-ED1.

A focus of RIIO-2 will be on whole-system outcomes. Ofgem intends network companies and system operators working together to ensure the energy system as a whole is efficient and delivers the best value to consumers. Ofgem is undertaking further work to clarify the definition of whole-system and the appropriate roles of the network companies in supporting this objective. Ofgem is still undecided on how DSO functions are to be treated. Ofgem will include a DSO reopener to reassess progress made in the establishment of DSO activities.

Ofgem will now shift focus to the development of the RIIO-ED2 ~~process.~~price control methodology, with the consultation expected to be published by the third quarter of 2020. WPD and PPL ~~have been~~continue to be fully engaged in the ~~RIIO-2 process and have responded to this consultation, which closed on October 15, 2019. At this stage,~~RIIO-ED2 process. PPL cannot predict the outcome of this process or the long-term impact the final RIIO-ED2 ~~framework~~price control will have on its financial condition or results of operations. Any decision for RIIO-ED2 will not be finalized until November 2022. The RIIO-ED2 price control will come into effect on April 1, 2023.

FERC Transmission Rate Filing

(PPL, LKE, LG&E and KU)

In ~~August~~ 2018, LG&E and KU ~~submitted an application~~applied to the FERC requesting elimination of certain on-going credits to a sub-set of transmission customers relating to the 1998 merger of LG~~&E’s~~&E's and KU's parent entities and the 2006 withdrawal of LG&E and KU from the Midcontinent Independent System Operator, Inc. (MISO), a regional transmission operator and energy market. The application ~~sought~~seeks termination of LG&E's and KU's commitment to provide certain Kentucky municipalities mitigation for certain horizontal market power concerns arising out of the 1998 ~~merger for certain transmission service between MISO and~~ LG&E and ~~KU. The affected transmission customers are a limited number of municipalities in Kentucky.~~KU merger and 2006 MISO withdrawal. The amounts at issue are generally waivers or credits granted to ~~such customers~~a limited number of Kentucky municipalities for either certain LG&E and KU or MISO transmission charges incurred ~~depending upon the direction of certain~~for transmission service ~~incurred by the municipalities.~~received. Due to the development of robust, accessible energy markets over time, LG&E and KU believe the mitigation commitments are no longer relevant or appropriate. OnIn March ~~21,~~ 2019, the FERC ~~issued an Order granting~~granted LG&E's and KU's request to remove the ~~on-going~~ongoing credits, conditioned upon the implementation by LG&E and KU of a transition mechanism for certain existing power supply arrangements, ~~which transition mechanism will be~~ subject to FERC review and approval. OnIn July ~~12,~~ 2019, LG&E and KU ~~submitted~~proposed their ~~proposed~~ transition mechanism to the ~~FERC. On~~FERC and in September ~~10,~~ 2019, the FERC ~~issued an order rejecting~~rejected the proposed transition ~~mechanism. On~~mechanism and issued a separate order providing clarifications of certain aspects of the March order. In October ~~10,~~ 2019, LG&E and KU filed ~~a request~~requests for rehearing and clarification on the two September ~~order.~~orders. In November 2019, the FERC granted LG&E and KU's and other parties' rehearing requests. Additionally, certain petitions for review of FERC's orders have been filed by multiple parties, including LG&E and KU, at the D.C. Circuit Court of Appeals. LG&E and KU cannot predict the outcome of ~~this proceeding.~~the proceedings. In February 2020, the D.C. Circuit Court of Appeals issued an order holding the various appeals in abeyance pending the FERC's rehearing process. LG&E and KU currently receive recovery of waivers and credits provided through other rate mechanisms.

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(PPL and PPL Electric)

Rate Case Proceedings

(~~PPL,~~ LKE ~~LG&E~~ and KU)

On September 28, 2018, LG&E and KU filed requests with the KPSC for an increase in annual base electricity rates and gas rates and the elimination of the TCJA bill credit mechanism. On April 30, 2019, the KPSC issued orders eliminating the TCJA bill credit mechanism and increasing annual base electricity and gas rates providing for an annual revenue increase of $187 million ($114 million at KU and $73 million at LG&E), based on a 9.725% return-on-equity. The new base rates and all elements of the orders became effective May 1, 2019. See Note 7 to the financial statements for additional information.

(~~KU)~~

OnIn July ~~12,~~ 2019, KU filed a request with the VSCC for an increase in annual Virginia base electricity ~~rates~~revenues of approximately $13 million, representing an increase of 18.2%. ~~KU's request is based on~~In January 2020, KU reached a partial settlement agreement including an ~~authorized 10.5% return on equity. Subject to regulatory review and approval, new rates would become~~increase in annual Virginia base electricity revenues of $9 million effective ~~April 12, 2020.~~

~~PUC Petition to Distribute TCJA Savings~~

(~~PPL and PPL Electric)~~

PPL Electric submitted a petition for approval with the PUC on October 4, 2019 to distribute the tax savings of $43 million associated with the TCJA for the period between January 1, 2018 and June 30, 2018. As of September 30, 2019, these tax savings are classified as a noncurrent regulatory liability. PPL Electric has proposed that these amounts be distributed over the period of JanuaryMay 1, 2020, ~~through December 31,~~representing an increase of 12.9%. A hearing on the settlement and certain tariff provisions was held in January 2020. ~~The petition is contingent upon PUC approval.~~On April 6, 2020, the VSCC issued an order approving the settlement and Hearing Examiner tariff provision recommendations.

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Results of Operations

(PPL)

The "Statement of Income Analysis" discussion below describes significant changes in principal line items on PPL's Statements of Income, comparing the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 with the same ~~periods~~period in ~~2018.~~2019. The "Segment Earnings" and "Adjusted Gross Margins" discussions for PPL provide a review of results by reportable segment. These discussions include non-GAAP financial measures, including "Earnings from Ongoing Operations" and "Adjusted Gross Margins," and provide explanations of the non-GAAP financial measures and a reconciliation of those measures to the most comparable GAAP measure.

Tables analyzing changes in amounts between periods within "Statement of Income Analysis," "Segment Earnings" and "Adjusted Gross Margins" are presented on a constant GBP to U.S. dollar exchange rate basis, where applicable, in order to isolate the impact of the change in the exchange rate on the item being explained. Results computed on a constant GBP to U.S. dollar exchange rate basis are calculated by translating current year results at the prior year weighted-average GBP to U.S. dollar exchange rate.

(PPL Electric, LKE, LG&E and KU)

A "Statement of Income ~~Analysis, Earnings and Adjusted Gross Margins"~~Analysis" is presented separately for PPL Electric, LKE, LG&E and KU. The "Statement of Income Analysis" discussion below describes significant changes in principal line items on the Statements of Income, comparing the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 with the same ~~periods~~period in ~~2018. The "Earnings" discussion provides a summary of earnings. The "Adjusted Gross Margins" discussion includes a reconciliation of non-GAAP financial measures to "Operating Income."~~2019.

(All Registrants)

The results for interim periods can be disproportionately influenced by numerous factors and developments and by seasonal variations. As such, the results of operations for interim periods do not necessarily indicate results or trends for the year or future periods.

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PPL: Statement of Income Analysis, Segment Earnings and Adjusted Gross Margins

Statement of Income Analysis

Net income for the ~~periods~~period ended ~~September 30~~March 31 includes the following results.


	Three Months							Nine Months							Three Months
	2019		2018		$ Change			2019		2018		$ Change			2020		2019		$ Change
Operating Revenues	$	1,933	$	1,872	$	61		$	5,815	$	5,846	$	(31	)	$	2,054	$	2,079	$	(25	)
Operating Expenses
Operation
Fuel	194		206		(12		)	556		609		(53		)	163		194		(31		)
Energy purchases	150		149		1			538		538		—			201		250		(49		)
Other operation and maintenance	480		479		1			1,452		1,453		(1		)	476		490		(14		)
Depreciation	306		275		31			890		817		73			317		284		33
Taxes, other than income	77		77		—			232		234		(2		)	80		80		—
Total Operating Expenses	1,207		1,186		21			3,668		3,651		17			1,237		1,298		(61		)
Other Income (Expense) - net	126		106		20			309		297		12			125		52		73
Interest Expense	259		244		15			746		718		28			248		241		7
Income Taxes	118		103		15			328		362		(34		)	140		126		14
Net Income	$	475	$	445	$	30		$	1,382	$	1,412	$	(30	)	$	554	$	466	$	88

Operating Revenues

The increase (decrease) in operating revenues ~~for the periods ended September 30, 2019 compared with 2018~~ was due to:


	Three Months			Nine Months			Three Months
Domestic:
PPL Electric Distribution price (a)	$	18		$	20
PPL Electric Distribution volumes (a)							$	(24	)
PPL Electric PLR (b)	6			11			(27		)
PPL Electric Transmission Formula Rate (c)	17			29			16
LKE Retail Rates (d)	42			77			49
LKE ECR(e)	21			40			19
LKE Fuel and other energy purchase prices(f)	(7		)	(16		)	(21		)
LKE Municipal supply ~~(e)~~(g)	(22		)	(37		)	(22		)
LKE Volumes ~~(f)~~(h)	9			(65		)	(38		)
Other	3			11			(8		)
Total Domestic	87			70			(56		)
U.K.:
Price	15			66			18
Volume	(10		)	(54		)
Foreign currency exchange rates	(27		)	(100		)	9
Other	(4		)	(13		)	4
Total U.K.	(26		)	(101		)	31
Total	$	61		$	(31	)	$	(25	)


(a)	~~Distribution price variances were~~The decrease was primarily due to ~~reconcilable cost recovery mechanisms approved by the PUC.~~warmer weather in 2020.


(b)	The ~~increase for the nine months ended September 30, 2019~~decrease was primarily due to ~~higher~~lower energy volumes ~~partially offset by~~of $16 million primarily due to warmer weather in 2020 and lower energy prices ~~and lower transmission enhancement expenses.~~of $11 million.


(c)	The increase ~~for the three months ended September 30, 2019~~ was primarily due to increased returns on capital investments. The increase for the nine months ended September 30, 2019 was primarily due to $60 million of increased returns on capital investments partially offset by a $27 million unfavorable impact of the TCJA which reduced the revenue requirement that went into effect June 1, 2018.


(d)	The ~~higher retail rates were~~increase was primarily due to higher base rates, inclusive of the termination of the TCJA bill credit mechanism, effective May 1, 2019.


(e)	The ~~decreases were~~increase was primarily due to higher recoverable depreciation expense as a result of higher depreciation rates effective May 1, 2019.


(f)	The decrease was primarily due to lower recoveries of fuel and energy purchases due to lower commodity costs.


(g)	The decrease was primarily due to the termination of eight supply contracts with Kentucky municipalities on April 30, ~~2019.~~2019


~~(f)~~(h)	The decrease ~~for the nine months ended September 30, 2019~~ was primarily due to weather.

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Fuel

Fuel decreased ~~$12~~$31 million ~~for the three months ended~~ ~~September 30, 2019~~ ~~compared with~~ ~~2018~~, primarily due to a $9$13 million decrease in volumes driven by weather, a $10 million decrease in commodity costs and an $8 million decrease in volumes driven by the termination of eight supply contracts with Kentucky municipalities on April 30, ~~2019, partially offset by a $3 million increase in volumes driven by weather in Kentucky.~~

~~Fuel decreased~~ ~~$53 million~~ ~~for the~~ ~~nine months endedSeptember 30, 2019~~ ~~compared with~~ ~~2018~~, primarily due to a $22 million decrease in commodity costs, a $21 million decrease in volumes driven by weather, and a $14 million decrease in volumes driven by the termination of eight supply contracts with Kentucky municipalities on April 30, 2019 in Kentucky.2019.

Energy Purchases

Energy purchases ~~remained flat for the nine months ended September 30, 2019 compared with 2018,~~decreased $49 million primarily due to ~~higher PLR volumes of $28 million, partially offset by~~ lower PLR prices of ~~$12~~$18 million and lower ~~transmission enhancement expenses~~PLR volumes of $8$14 million at PPL Electric as well as a $5$14 million decrease in commodity costs ~~and a $4 million decrease in volumes due to expiration of a capacity purchase tolling agreement~~ at ~~LG&E.~~LKE.

Other Operation and Maintenance

The increase (decrease) in other operation and maintenance ~~for the periods ended September 30, 2019 compared with 2018~~ was due to:


	Three Months			Nine Months			Three Months
Domestic:
PPL Electric storm costs							$	(16	)
LKE plant operations and maintenance	$	(7	)	$	(9	)	(3		)
LKE gas distribution maintenance and compliance	2			6
LKE transmission credits	3			10
LKE DSM program costs	(4		)	(11		)
Storm Costs	(13		)	(13		)
Vegetation Management	6			10
Other operation and maintenance of Safari Energy (a)	5			18
LKE administrative and general							(5		)
Other	17			11			(2		)
U.K.:
Pension							2
Foreign currency exchange rates	(6		)	(21		)	2
Third-party engineering	(4		)	(9		)	2
Other	2			7			6
Total	$	1		$	(1	)	$	(14	)


~~(a)~~	~~Represents the increase for the three and nine months ended September 30. 2019 resulting from the other operation and maintenance expense of Safari Energy, which was acquired on June 1, 2018.~~

Depreciation

The increase ~~(decrease)~~ in depreciation ~~for the periods ended September 30, 2019 compared with 2018~~ was due to:


	Three Months			Nine Months			Three Months
Additions to PP&E, net	$	16		$	52		$	11
Foreign currency exchange rates	(3		)	(11		)	1
Depreciation rates (a)	20			33			19
Other	(2		)	(1		)	2
Total	$	31		$	73		$	33


(a)	Higher depreciation rates were effective May 1, 2019 at LG&E and KU.

Other Income (Expense) - net

The increase (decrease) in other income (expense) - net was due to:



	Three Months
Economic foreign currency exchange contracts (Note 14)	$	95
Defined benefit plans - non-service credits (Note 9)	(12		)
Other	(10		)
Total	$	73

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~~Other Income (Expense) - net~~

~~The increase (decrease) in other income (expense) - net for the periods ended September 30, 2019 compared with 2018 was due to:~~

Three Months Nine Months
Economic foreign currency exchange contracts (Note 15) $ 4
$ (36 )
Defined benefit plans - non-service credits (Note 10) 16
42
Other —
6
Total $ 20
$ 12

Interest Expense

The increase (decrease) in interest expense ~~for the periods ended September 30, 2019 compared with 2018~~ was due to:


	Three Months			Nine Months			Three Months
Long-term debt interest expense	$	17		$	31		$	8
Short-term debt interest expense	3			7			(2		)
Foreign currency exchange rates	(5		)	(17		)	1
Other	—			7
Total	$	15		$	28		$	7

Income Taxes

~~The increase (decrease)~~Income taxes increased by $14 million primarily due to a change in pre-tax income. See Note 6 to the Financial Statements for additional information on income ~~taxes for the periods ended September 30, 2019 compared with 2018 was due to:~~taxes.

Three Months Nine Months
Change in pre-tax income $ 15
$ (14 )
Valuation allowances (a) 2
4
Deferred tax impact of Kentucky state tax reform (b) —
(9 )
Kentucky recycling credit, net of federal income tax expense (a) —
(20 )
Other (2 ) 5
Total $ 15
$ (34 )

~~(a)~~


~~(b)~~	During the second quarter of 2018, LKE recorded deferred income tax expense, primarily associated with LKE's non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018.

Segment Earnings

PPL's Net Income by reportable segment for the ~~periods~~period ended ~~September 30~~March 31 was as follows:


	Three Months									Nine Months									Three Months
	2019			2018			$ Change			2019			2018			$ Change			2020			2019			$ Change
U.K. Regulated	$	236		$	245		$	(9	)	$	784		$	836		$	(52	)	$	340		$	264		$	76
Kentucky Regulated	150			122			28			364			332			32			127			117			10
Pennsylvania Regulated	118			112			6			333			335			(2		)	118			121			(3		)
Corporate and Other (a)	(29		)	(34		)	5			(99		)	(91		)	(8		)	(31		)	(36		)	5
Net Income	$	475		$	445		$	30		$	1,382		$	1,412		$	(30	)	$	554		$	466		$	88


(a)	Primarily represents financing and certain other costs incurred at the corporate level that have not been allocated or assigned to the segments, which are presented to reconcile segment information to PPL's consolidated results.

~~Table of Contents~~

Earnings from Ongoing Operations

Management utilizes "Earnings from Ongoing Operations" as a non-GAAP financial measure that should not be considered as an alternative to net income, an indicator of operating performance determined in accordance with GAAP. PPL believes that Earnings from Ongoing Operations is useful and meaningful to investors because it provides management's view of PPL's earnings performance as another criterion in making investment decisions. In addition, PPL's management uses Earnings from Ongoing Operations in measuring achievement of certain corporate performance goals, including targets for certain executive incentive compensation. Other companies may use different measures to present financial performance.

Earnings from Ongoing Operations is adjusted for the impact of special items. Special items are presented in the financial tables on an after-tax basis with the related income taxes on special items separately disclosed. Income taxes on special items, when applicable, are calculated based on the ~~effective~~statutory tax rate of the entity where the activity is recorded. Special items may include items such as:

• Unrealized gains or losses on foreign currency economic hedges (as discussed below).

• Gains and losses on sales of assets not in the ordinary course of business.

• Impairment charges.

• Significant workforce reduction and other restructuring effects.

• Acquisition and divestiture-related adjustments.

• Other charges or credits that are, in management's view, non-recurring or otherwise not reflective of the company's ongoing operations.

Unrealized gains or losses on foreign currency economic hedges include the changes in fair value of foreign currency contracts used to hedge GBP-denominated anticipated earnings. The changes in fair value of these contracts are recognized immediately within GAAP earnings. Management believes that excluding these amounts from Earnings from Ongoing Operations until settlement of the contracts provides a better matching of the financial impacts of those contracts with the economic value of PPL's underlying hedged earnings. See Note 1514 to the Financial Statements and "Risk Management" below for additional information on foreign currency economic activity.

Table of Contents

PPL's Earnings from Ongoing Operations by reportable segment for the ~~periods~~period ended ~~September 30~~March 31 were as follows:


	Three Months									Nine Months									Three Months
	2019			2018			$ Change			2019			2018			$ Change			2020			2019			$ Change
U.K. Regulated	$	205		$	214		$	(9	)	$	773		$	730		$	43		$	298		$	304		$	(6	)
Kentucky Regulated	150			120			30			364			339			25			127			117			10
Pennsylvania Regulated	118			117			1			333			340			(7		)	118			121			(3		)
Corporate and Other	(28		)	(29		)	1			(95		)	(86		)	(9		)	(29		)	(34		)	5
Earnings from Ongoing Operations	$	445		$	422		$	23		$	1,375		$	1,323		$	52		$	514		$	508		$	6

See "Reconciliation of Earnings from Ongoing Operations" below for a reconciliation of this non-GAAP financial measure to Net Income.

U.K. Regulated Segment

The U.K. Regulated segment consists of PPL Global, which primarily includes WPD's regulated electricity distribution operations, the results of hedging the translation of WPD's earnings from GBP into U.S. dollars, and certain costs, such as U.S. income taxes, administrative costs and certain acquisition-related financing costs. The U.K. Regulated segment represents ~~57%~~61% of PPL's Net Income for the ~~nine~~three months ended ~~September 30, 2019~~March 31, 2020 and ~~38%~~39% of PPL's assets at ~~September 30, 2019.~~March 31, 2020.

Net Income and Earnings from Ongoing Operations for the ~~periods~~period ended ~~September 30~~March 31 include the following results.

~~Table of Contents~~



	Three Months
	2020		2019			$ Change
Operating revenues	$	614	$	583		$	31
Other operation and maintenance	129		118			11
Depreciation	66		62			4
Taxes, other than income	33		32			1
Total operating expenses	228		212			16
Other Income (Expense) - net	130		45			85
Interest Expense	102		99			3
Income Taxes	74		53			21
Net Income	340		264			76
Less: Special Items	42		(40		)	82
Earnings from Ongoing Operations	$	298	$	304		$	(6	)

Three Months Nine Months
2019 2018 $ Change 2019 2018 $ Change
Operating revenues $ 491
$ 517
$ (26 ) $ 1,615

$ 1,716
$ (101 )
Other operation and maintenance 125
131
(6 ) 376
400
(24 )
Depreciation 60
61
(1 ) 186
186
—
Taxes, other than income 32
33
(1 ) 96
101
(5 )
Total operating expenses 217
225
(8 ) 658
687
(29 )
Other Income (Expense) - net 120
102
18
289
284
5
Interest Expense 110
106
4
305
310
(5 )
Income Taxes 48
43
5
157
167
(10 )
Net Income 236

245
(9 ) 784

836
(52 )
Less: Special Items 31
31
—
11
106
(95 )
Earnings from Ongoing Operations $ 205
$ 214
$ (9 ) $ 773
$ 730
$ 43

The following after-tax gains (losses), which management considers special items, impacted the U.K. Regulated segment's results and are excluded from Earnings from Ongoing Operations during the ~~periods~~period ended ~~September 30.~~March 31.

Income Statement Line Item Three Months Nine Months
2019 2018 2019 2018
Foreign currency economic hedges, net of tax of ($8), ($7), ($4), ($27) (a) Other Income (Expense) - net $ 31
$ 28
$ 15
$ 103
Other, net of tax of $0, $0, $1, $0 (b) Other operation and maintenance —
—
(4 ) —
U.S. tax reform (c) Income Taxes —
3
—
3
Total Special Items $ 31
$ 31
$ 11
$ 106



	Income Statement Line Item	Three Months
	Income Statement Line Item	2020		2019
Foreign currency economic hedges, net of tax of ($11), $11 (a)	Other Income (Expense) - net	$	42	$	(40	)
Total Special Items		$	42	$	(40	)


(a)	Unrealized gains (losses) on contracts that economically hedge anticipated GBP-denominated earnings.


~~(b)~~	~~Settlement of a contractual dispute.~~


~~(c)~~	~~Adjustments to certain provisional amounts recognized in the December 31, 2017 Statement of Income related to the enactment of the TCJA.~~

The changes in the components of the U.K. Regulated segment's results between these periods are due to the factors set forth below, which reflect amounts classified as U.K. Adjusted Gross Margins, the items that management considers special and the effects of movements in foreign currency exchange, including the effects of foreign currency hedge contracts, on separate lines and not in their respective Statement of Income line items.

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Three Months Nine Months
U.K.

U.K. Adjusted Gross Margins $ 3
$ 7
Other operation and maintenance (2 ) —
Depreciation (2 ) (11 )
Other Income (Expense) - net 18
57
Interest expense (10 ) (13 )
Income taxes (4 ) (8 )
U.S.
Income taxes 1
2
Other —
(1 )
Foreign currency exchange, after-tax (13 ) 10
Earnings from Ongoing Operations (9 ) 43
Special items, after-tax —
(95 )
Net Income $ (9 ) $ (52 )



	Three Months
U.K.
U.K. Adjusted Gross Margins	$	20
Other operation and maintenance	(10		)
Depreciation	(4		)
Other Income (Expense) - net	(11		)
Interest expense	(2		)
Income taxes	1
U.S.
Income taxes	(1		)
Other	3
Foreign currency exchange, after-tax	(2		)
Earnings from Ongoing Operations	(6		)
Special items, after-tax	82
Net Income	$	76

U.K.

See "Adjusted Gross Margins - Changes in Adjusted Gross Margins" for an explanation of U.K. Adjusted Gross Margins.

Higher other operation and maintenance expense primarily from increases in various costs that were not individually significant in comparison to the prior year.

Lower other income (expense) - net ~~for the three and nine month periods~~ primarily from ~~higher~~lower pension income.

~~Table of Contents~~

Kentucky Regulated Segment

The Kentucky Regulated segment consists primarily of LKE's regulated electricity generation, transmission and distribution operations conducted by LG&E and KU, as well as LG&E's regulated distribution and sale of natural gas. In addition, certain acquisition-related financing costs are allocated to the Kentucky Regulated segment. The Kentucky Regulated segment represents ~~26%~~23% of PPL's Net Income for the ~~nine~~three months ended ~~September 30, 2019~~March 31, 2020 and ~~35%~~34% of PPL's assets at ~~September 30, 2019.~~March 31, 2020.

Net Income and Earnings from Ongoing Operations for the ~~periods~~period ended ~~September 30~~March 31 include the following results.


	Three Months							Nine Months								Three Months
	2019		2018		$ Change			2019		2018			$ Change			2020		2019		$ Change
Operating revenues	$	844	$	802	$	42		$	2,421	$	2,417		$	4		$	825	$	845	$	(20	)
Fuel	194		206		(12		)	556		609			(53		)	163		194		(31		)
Energy purchases	19		22		(3		)	125		135			(10		)	57		79		(22		)
Other operation and maintenance	205		216		(11		)	627		632			(5		)	204		214		(10		)
Depreciation	144		119		25			402		354			48			149		123		26
Taxes, other than income	19		18		1			55		53			2			18		18		—
Total operating expenses	581		581		—			1,765		1,783			(18		)	591		628		(37		)
Other Income (Expense) - net	2		—		2			2		(2		)	4					—		—
Interest Expense	74		69		5			222		205			17			75		70		5
Income Taxes	41		30		11			72		95			(23		)	32		30		2
Net Income	150		122		28			364		332			32			127		117		10
Less: Special Items(a)	—		2		(2		)	—		(7		)	7			—		—		—
Earnings from Ongoing Operations	$	150	$	120	$	30		$	364	$	339		$	25		$	127	$	117	$	10

The following after-tax gains (losses), which management considers special items, impacted the Kentucky Regulated segment's results and are excluded from Earnings from Ongoing Operations during the periods ended September 30.

Income Statement Line Item Three Months Nine Months
2019 2018 2019 2018
Kentucky state tax reform (a) Income Taxes $ —
$ —
$ —
$ (9 )
U.S. tax reform (b) Income Taxes —
2
—
2
Total Special Items $ —
$ 2
$ —
$ (7 )


(a)	~~During~~There are no items that management considers special for the second quarter of 2018, LKE recorded deferred income tax expense, primarily associated with LKE's non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018.


~~(b)~~	~~Adjustments to certain provisional amounts recognized in the December 31, 2017 Statement of Income related to the enactment of the TCJA.~~periods presented.

The changes in the components of the Kentucky Regulated segment's results between these periods are due to the factors set forth below, which reflect amounts classified as Kentucky Adjusted Gross Margins ~~and the items that management considers special,~~ on separate lines and not in their respective Statement of Income line items.

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Three Months Nine Months
Kentucky Adjusted Gross Margins $ 44
$ 42
Other operation and maintenance 10
1
Depreciation (10 ) (19 )
Taxes, other than income (2 ) (2 )
Other Income (Expense) - net 2
4
Interest Expense (5 ) (17 )
Income Taxes (9 ) 16
Earnings from Ongoing Operations 30
25
Special items, after-tax (2 ) 7
Net Income $ 28
$ 32



	Three Months
Kentucky Adjusted Gross Margins	$	17
Other operation and maintenance	9
Depreciation	(8		)
Taxes, other than income	(1		)
Interest Expense	(5		)
Income Taxes	(2		)
Net Income	$	10

See "Adjusted Gross Margins - Changes in Adjusted Gross Margins" for an explanation of Kentucky Adjusted Gross Margins.

~~Table of Contents~~

Lower other operation and maintenance expense ~~for~~primarily from decreases in various costs that were not individually significant in comparison to the ~~three month period primarily due to a decrease in storm costs.~~prior year.

Higher depreciation expense ~~for the three month period~~ primarily due to a $6$5 million increase related to higher depreciation rates effective May 1, 2019 and a $4$3 million increase related to additional assets placed into service, net of retirements.

Higher depreciation expense for the nine month period primarily due to a $10 million increase related to higher depreciation rates effective May 1, 2019 and a $9 million increase related to additional assets placed into service, net of retirements.

~~Higher interest expense for the nine month period primarily due to increased borrowings and higher interest rates.~~

~~Higher income taxes for the three month period primarily due to the higher pre-tax income.~~

~~Lower income taxes for the nine month period primarily due to the recording of a deferred tax benefit related to a Kentucky recycling credit.~~

Pennsylvania Regulated Segment

The Pennsylvania Regulated segment includes the regulated electricity transmission and distribution operations of PPL Electric. In addition, certain costs are allocated to the Pennsylvania Regulated segment. The Pennsylvania Regulated segment represents ~~24%~~21% of PPL's Net Income for the ~~nine~~three months ended ~~September 30, 2019~~March 31, 2020 and ~~27%~~26% of PPL's assets at ~~September 30, 2019.~~March 31, 2020.

Net Income and Earnings from Ongoing Operations for the ~~periods~~period ended ~~September 30~~March 31 include the following results.

Three Months Nine Months

2019 2018 $ Change 2019 2018 $ Change
Operating revenues $ 590
$ 548
$ 42
$ 1,756
$ 1,704
$ 52
Energy purchases 132
127
5
413
403
10
Other operation and maintenance 137
127
10
417
419
(2 )
Depreciation 99
89
10
290
262
28
Taxes, other than income 29
27
2
84
81
3
Total operating expenses 397
370
27
1,204
1,165
39
Other Income (Expense) - net 8
9
(1 ) 21
23
(2 )
Interest Expense 43
40
3
126
116
10
Income Taxes 40
35
5
114
111
3
Net Income 118
112
6
333
335
(2 )
Less: Special Item —

(5 ) 5
—

(5 ) 5
Earnings from Ongoing Operations $ 118
$ 117
$ 1
$ 333
$ 340
$ (7 )

The following after-tax gains (losses), which management considers special items, impacted the Pennsylvania Regulated segment's results and are excluded from Earnings from Ongoing Operations during the periods ended September 30.

Income Statement Line Item Three Months Nine Months
2019 2018 2019 2018
IT transformation, net of tax of $0, $2, $0, $2 (a) Other operation and maintenance $ —
$ (5 ) $ —
$ (5 )
Total Special Item $ —
$ (5 ) $ —
$ (5 )



	Three Months
	2020		2019		$ Change
Operating revenues	$	608	$	645	$	(37	)
Energy purchases	144		171		(27		)
Other operation and maintenance	137		150		(13		)
Depreciation	98		95		3
Taxes, other than income	30		31		(1		)
Total operating expenses	409		447		(38		)
Other Income (Expense) - net	4		7		(3		)
Interest Expense	44		42		2
Income Taxes	41		42		(1		)
Net Income	118		121		(3		)
Less: Special Item (a)	—		—		—
Earnings from Ongoing Operations	$	118	$	121	$	(3	)

(a)

~~In June 2018, PPL EU Services' IT department announced an internal reorganization, which was substantially completed in~~There are no items that management considers special for the third quarter of 2018. As a result, $5 million of after-tax costs, which includes separation benefits as well as outside services for strategic consulting to establish the new IT organization, were incurred.periods presented.

The changes in the components of the Pennsylvania Regulated segment's results between these periods are due to the factors set forth below, which reflect amounts classified as Pennsylvania Adjusted Gross Margins on a separate line and not in their respective Statement of Income line items.



	Three Months
Pennsylvania Adjusted Gross Margins	$	(2	)
Other operation and maintenance	5
Depreciation	(1		)
Taxes, other than income	(1		)
Other Income (Expense) - net	(3		)
Interest Expense	(2		)
Income Taxes	1
Net Income	$	(3	)

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Three Months Nine Months
Pennsylvania Adjusted Gross Margins $ 24
$ 30
Other operation and maintenance (10 ) (5 )
Depreciation (6 ) (18 )
Taxes, other than income —
(1 )
Other Income (Expense) - net (1 ) (2 )
Interest Expense (3 ) (10 )
Income Taxes (3 ) (1 )
Earnings from Ongoing Operations 1
(7 )
Special Item, after tax 5
5
Net Income $ 6
$ (2 )

See "Adjusted Gross Margins - Changes in Adjusted Gross Margins" for an explanation of Pennsylvania Adjusted Gross Margins.

~~Higher~~Lower other operation and maintenance expense ~~for the three month period~~ primarily due to ~~a $4~~lower storm costs of $11 million, ~~increase related to~~partially offset by higher ~~vegetation management~~project cancellation costs ~~and a $2 million increase related to higher support costs.~~of $6 million.

Higher depreciation expense for the nine month period primarily due to additional assets placed into service, related to the ongoing efforts to ensure the reliability of the delivery system and the replacement of aging infrastructure, net of retirements.

Higher interest expense for the nine month period primarily due to the June 2018 issuance of $400 million of 4.15% First Mortgage Bonds due 2048 and the September 2019 issuance of $400 million of 3.00% First Mortgage Bonds due 2049.

Reconciliation of Earnings from Ongoing Operations

The following tables contain after-tax gains (losses), in total, which management considers special items, that are excluded from Earnings from Ongoing Operations and a reconciliation to PPL's "Net Income" for the ~~periods~~period ended ~~September 30.~~March 31.

2019 Three Months

U.K.
Regulated

KY
Regulated

PA
Regulated

Corporate
and Other
Total
Net Income $ 236
$ 150
$ 118
$ (29 ) $ 475
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of ($8) 31
—
—
—
31
Talen litigation costs, net of tax of $0 (a) —
—
—
(1 ) (1 )
Total Special Items 31
—
—
(1 ) 30
Earnings from Ongoing Operations $ 205
$ 150
$ 118
$ (28 ) $ 445

2018 Three Months
U.K.
Regulated KY
Regulated PA
Regulated Corporate
and Other Total
Net Income $ 245
$ 122
$ 112
$ (34 ) $ 445
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of ($7) 28
—
—
—
28
U.S. tax reform 3
2
—
(5 ) —
IT transformation, net of tax of $2 —
—
(5 ) —
(5 )
Total Special Items 31
2
(5 ) (5 ) 23
Earnings from Ongoing Operations $ 214
$ 120
$ 117
$ (29 ) $ 422

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	2019 Nine Months															2020 Three Months
	U.K. Regulated			KY Regulated			PA Regulated			Corporate and Other			Total			U.K. Regulated			KY Regulated		PA Regulated		Corporate and Other			Total
Net Income	$	784		$	364		$	333		$	(99	)	$	1,382		$	340		$	127	$	118	$	(31	)	$	554
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of ($4)	15			—			—			—			15
Foreign currency economic hedges, net of tax of ($11)																42			—		—		—			42
Talen litigation costs, net of tax of $1 (a)	—			—			—			(4		)	(4		)	—			—		—		(2		)	(2		)
Other, net of tax of $1	(4		)	—			—			—			(4		)
Total Special Items	11			—			—			(4		)	7			42			—		—		(2		)	40
Earnings from Ongoing Operations	$	773		$	364		$	333		$	(95	)	$	1,375		$	298		$	127	$	118	$	(29	)	$	514

	2018 Nine Months															2019 Three Months
	U.K. Regulated			KY Regulated			PA Regulated			Corporate and Other			Total			U.K. Regulated			KY Regulated		PA Regulated		Corporate and Other			Total
Net Income	$	836		$	332		$	335		$	(91	)	$	1,412		$	264		$	117	$	121	$	(36	)	$	466
Less: Special Items (expense) benefit:
Foreign currency economic hedges, net of tax of ($27)	103			—			—			—			103
U.S. tax reform	3			2			—			(5		)	—
Kentucky state tax reform	—			(9		)	—			—			(9		)
IT transformation, net of tax of $2	—			—			(5		)	—			(5		)
Foreign currency economic hedges, net of tax of $11																(40		)	—		—		—			(40		)
Talen litigation costs, net of tax of $0 (a)																—			—		—		(2		)	(2		)
Total Special Items	106			(7		)	(5		)	(5		)	89			(40		)	—		—		(2		)	(42		)
Earnings from Ongoing Operations	$	730		$	339		$	340		$	(86	)	$	1,323		$	304		$	117	$	121	$	(34	)	$	508


(a)	PPL incurred legal expenses related to litigation with its former affiliate, Talen ~~Montana, and related cases.~~Montana. See Note 1110 to the Financial Statements for additional information.

Adjusted Gross Margins

Management also utilizes the following non-GAAP financial measures as indicators of performance for its businesses:

"U.K. Adjusted Gross Margins" is a single financial performance measure of the electricity distribution operations of the U.K. Regulated segment. In calculating this measure, direct costs such as connection charges from National Grid, which owns and manages the electricity transmission network in England and Wales, and Ofgem license fees (recorded in "Other operation and maintenance" on the Statements of Income) are deducted from operating revenues, as they are costs passed through to customers. As a result, this measure represents the net revenues from the delivery of electricity across WPD's distribution network in the U.K. and directly related activities.

"Kentucky Adjusted Gross Margins" is a single financial performance measure of the electricity generation, transmission and distribution operations of the Kentucky Regulated segment, ~~LKE, LG&E and KU,~~ as well as the Kentucky Regulated segment's ~~LKE's and LG&E's~~ distribution and sale of natural gas. In calculating this measure, fuel, energy purchases and certain variable costs of production (recorded in "Other operation and maintenance" on the Statements of Income) are deducted from operating revenues. In addition, certain other expenses, recorded in "Other operation and maintenance", "Depreciation" and "Taxes, other than income" on the Statements of Income, associated with approved cost recovery mechanisms are offset against the recovery of those expenses, which are included in revenues. These mechanisms allow for direct recovery of these expenses and, in some cases, returns on capital investments and performance incentives. As a result, this measure represents the net revenues from electricity and gas operations.

"Pennsylvania Adjusted Gross Margins" is a single financial performance measure of the electricity transmission and distribution operations of the Pennsylvania Regulated ~~segment and PPL Electric.~~segment. In calculating this measure, utility revenues and expenses

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associated with approved recovery mechanisms, including energy provided as a PLR, are offset with minimal impact on earnings. Costs associated with these mechanisms are recorded in "Energy purchases," "Other operation and maintenance," (which are primarily Act 129, Storm Damage and Universal Service program costs), "Depreciation," (which is primarily related to the Act 129 Smart Meter program) and "Taxes, other than income," (which is primarily gross receipts tax) on the Statements of Income. This measure represents the net revenues from the Pennsylvania Regulated segment's ~~and PPL Electric's~~ electricity delivery operations.

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These measures are not intended to replace "Operating Income," which is determined in accordance with GAAP, as an indicator of overall operating performance. Other companies may use different measures to analyze and report their results of operations. Management believes these measures provide additional useful criteria to make investment decisions. These performance measures are used, in conjunction with other information, by senior management and PPL's Board of Directors to manage operations and analyze actual results compared with budget.

Changes in Adjusted Gross Margins

The following table shows Adjusted Gross Margins by PPL's reportable segment and by component, as applicable, for the ~~periods~~period ended ~~September 30~~March 31 as well as the change between ~~periods.~~period. The factors that gave rise to the changes are described following the table.


	Three Months							Nine Months							Three Months
	2019		2018		$ Change			2019		2018		$ Change			2020		2019		$ Change
U.K. Regulated
U.K. Adjusted Gross Margins	$	446	$	467	$	(21	)	$	1,492	$	1,578	$	(86	)	$	575	$	546	$	29
Impact of changes in foreign currency exchange rates					(24		)					(93		)					9
U.K. Adjusted Gross Margins excluding impact of foreign currency exchange rates					$	3						$	7						$	20

Kentucky Regulated
Kentucky Adjusted Gross Margins
LG&E	$	262	$	240	$	22		$	720	$	697	$	23
KU	310		288		22			866		847		19
Total Kentucky Adjusted Gross Margins	$	572	$	528	$	44		$	1,586	$	1,544	$	42		$	547	$	530	$	17

Pennsylvania Regulated
Pennsylvania Adjusted Gross Margins
Distribution	$	232	$	225	$	7		$	696	$	695	$	1		$	242	$	260	$	(18	)
Transmission	155		138		17			440		411		29			159		143		16
Total Pennsylvania Adjusted Gross Margins	$	387	$	363	$	24		$	1,136	$	1,106	$	30		$	401	$	403	$	(2	)

U.K. Adjusted Gross Margins

U.K. Adjusted Gross Margins, excluding the impact of changes in foreign currency exchange rates, increased for the three months ended September 30, 2019 compared with 2018, primarily due to $15 million from the April 1, 2019 price increase, partially offset by $10 million of lower volumes.

U.K. Adjusted Gross Margins, excluding the impact of changes in foreign currency exchange rates, increased ~~for the nine months ended September 30, 2019 compared with 2018,~~ primarily due to ~~$66 million from~~ the April 1, ~~2018 and~~ 2019 price ~~increases, partially offset by $54 million of lower volumes.~~increase.

Kentucky Adjusted Gross Margins

Kentucky Adjusted Gross Margins increased ~~for the three months ended September 30, 2019 compared with 2018,~~ primarily due to higher retail rates approved by the KPSC of ~~$42~~$49 million, ~~($15 million at LG&E and $27 million at KU),~~ inclusive of the termination of the TCJA bill credit mechanism, ~~and $9~~partially offset by $17 million of ~~increased~~decreased sales volumes primarily due to weather ~~($4 million at LG&E~~ and ~~$5 million at KU). This was partially offset by~~ a $14 million decrease ~~at KU primarily~~ due to the termination of eight supply contracts with Kentucky municipalities on April 30, 2019.

~~Kentucky~~Pennsylvania Adjusted Gross Margins ~~increased for the nine months ended September 30, 2019 compared with 2018, primarily~~

Distribution

Distribution Adjusted Gross Margins decreased $26 million due to ~~higher retail rates approved by the KPSC~~lower volumes primarily as a result of ~~$77 million ($29 million at LG&E and $48 million at KU), inclusive of the termination of the TCJA bill credit mechanism. This was~~warmer weather in 2020, partially offset by ~~$27~~$8 million of decreased sales volumes primarily due to weather ($12 million at LG&E and $15 million at KU) and a $22 million decrease at KU primarily due to the termination of eight supply contracts with Kentucky municipalitiesreturns on ~~April 30, 2019.~~additional distribution system improvement capital investments.

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~~Pennsylvania Adjusted Gross Margins~~

~~Distribution~~

Distribution Adjusted Gross Margins increased for the three months ended September 30, 2019 compared with 2018, primarily due to returns on additional distribution system improvement capital investments.

Transmission

Transmission Adjusted Gross Margins increased ~~for the three months ended September 30, 2019 compared with 2018,~~ primarily due to ~~an increase from returns on additional transmission capital investments focused on replacing aging infrastructure.~~

~~Transmission Adjusted Gross Margins increased for the nine months ended September 30, 2019 compared with 2018, primarily due to an increase of $60 million from~~ returns on additional transmission capital investments focused on replacing aging infrastructure and improving ~~reliability, partially offset by $27 million from the impact of the reduced U.S. federal corporate income taxes as a result of the TCJA in the first five months of 2019.~~reliability.

Reconciliation of Adjusted Gross Margins

The following tables contain the components from the Statement of Income that are included in the non-GAAP financial measures and a reconciliation to PPL's "Operating Income" for the periods ended ~~September 30.~~March 31.

2019 Three Months
U.K.
Adjusted Gross
Margins Kentucky
Adjusted Gross
Margins Pennsylvania Adjusted Gross
Margins Other (a) Operating
Income (b)
Operating Revenues $ 481
(c) $ 844
$ 590
$ 18
$ 1,933
Operating Expenses
Fuel —
194
—
—
194
Energy purchases —
19
132
(1 ) 150
Other operation and maintenance 35
25
30
390
480
Depreciation —
33
14
259
306
Taxes, other than income —
1
27
49
77
Total Operating Expenses 35
272
203
697
1,207
Total $ 446
$ 572
$ 387
$ (679 ) $ 726

2018 Three Months
U.K.
Adjusted Gross
Margins Kentucky
Adjusted Gross
Margins Pennsylvania Adjusted Gross
Margins Other (a) Operating
Income (b)
Operating Revenues $ 508
(c) $ 802
$ 548
$ 14
$ 1,872
Operating Expenses
Fuel —
206
—
—
206
Energy purchases —
22
127
—
149
Other operation and maintenance 41
26
23
389
479
Depreciation —
18
10
247
275
Taxes, other than income —
2
25
50
77
Total Operating Expenses 41
274
185
686
1,186
Total $ 467
$ 528
$ 363
$ (672 ) $ 686

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	2020 Three Months
	U.K. Adjusted Gross Margins			Kentucky Adjusted Gross Margins		Pennsylvania Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	605	(c)	$	825	$	608	$	16		$	2,054
Operating Expenses
Fuel	—			163		—		—			163
Energy purchases	—			57		144		—			201
Other operation and maintenance	30			21		23		402			476
Depreciation	—			37		12		268			317
Taxes, other than income	—			—		28		52			80
Total Operating Expenses	30			278		207		722			1,237
Total	$	575		$	547	$	401	$	(706	)	$	817

	2019 Three Months
	U.K. Adjusted Gross Margins			Kentucky Adjusted Gross Margins		Pennsylvania Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	574	(c)	$	845	$	645	$	15		$	2,079
Operating Expenses
Fuel	—			194		—		—			194
Energy purchases	—			79		171		—			250
Other operation and maintenance	28			22		31		409			490
Depreciation	—			19		10		255			284
Taxes, other than income	—			1		30		49			80
Total Operating Expenses	28			315		242		713			1,298
Total	$	546		$	530	$	403	$	(698	)	$	781

2019 Nine Months
U.K.
Adjusted Gross
Margins Kentucky
Adjusted Gross
Margins Pennsylvania Adjusted Gross
Margins Other (a) Operating
Income (b)
Operating Revenues $ 1,586
(c) $ 2,421
$ 1,756
$ 52
$ 5,815
Operating Expenses
Fuel —
556
—
—
556
Energy purchases —
125
413
—
538
Other operation and maintenance 94
70
92
1,196
1,452
Depreciation —
81
36
773
890
Taxes, other than income —
3
79
150
232
Total Operating Expenses 94
835
620
2,119
3,668
Total $ 1,492
$ 1,586
$ 1,136
$ (2,067 ) $ 2,147

2018 Nine Months
U.K.
Adjusted Gross
Margins Kentucky
Adjusted Gross
Margins Pennsylvania Adjusted Gross
Margins Other (a) Operating
Income (b)
Operating Revenues $ 1,687
(c) $ 2,417
$ 1,704
$ 38
$ 5,846
Operating Expenses
Fuel —
609
—
—
609
Energy purchases —
135
403
—
538
Other operation and maintenance 109
74
92
1,178
1,453
Depreciation —
52
26
739
817
Taxes, other than income —
3
77
154
234
Total Operating Expenses 109
873
598
2,071
3,651
Total $ 1,578
$ 1,544
$ 1,106
$ (2,033 ) $ 2,195


(a)	Represents amounts excluded from Adjusted Gross Margins.


(b)	As reported on the Statements of Income.


(c)	Excludes ancillary revenues of ~~$10 million and $29~~$9 million for the three ~~and nine~~ months ended ~~September 30, 2019~~March 31, 2020 and ~~$8 million and $29 million for the three and nine months ended September 30, 2018.~~2019.

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PPL Electric: Statement of Income Analysis ~~Earnings and Adjusted Gross Margins~~

Statement of Income Analysis

Net income for the periods ended ~~September 30~~March 31 includes the following results.


	Three Months							Nine Months							Three Months
	2019		2018		$ Change			2019		2018		$ Change			2020		2019		$ Change
Operating Revenues	$	590	$	548	$	42		$	1,756	$	1,704	$	52		$	608	$	645	$	(37	)
Operating Expenses
Operation
Energy purchases	132		127		5			413		403		10			144		171		(27		)
Other operation and maintenance	137		127		10			417		419		(2		)	137		150		(13		)
Depreciation	99		89		10			290		262		28			98		95		3
Taxes, other than income	29		27		2			84		81		3			30		31		(1		)
Total Operating Expenses	397		370		27			1,204		1,165		39			409		447		(38		)
Other Income (Expense) - net	7		5		2			18		18		—			3		5		(2		)
Interest Income from Affiliate	1		4		(3		)	3		5		(2		)	1		2		(1		)
Interest Expense	43		41		2			126		117		9			44		42		2
Income Taxes	40		35		5			114		111		3			41		42		(1		)
Net Income	$	118	$	111	$	7		$	333	$	334	$	(1	)	$	118	$	121	$	(3	)

Operating Revenues

The increase (decrease) in operating revenues was due to:



	Three Months
Distribution volume (a)	$	(24	)
PLR (b)	(27		)
Transmission Formula Rate (c)	16
Other	(2		)
Total	$	(37	)


(a)	The decrease was primarily due to warmer weather in 2020.


(b)	The decrease was primarily due to lower energy volumes of $16 million primarily due to warmer weather in 2020 and lower energy prices of $11 million.


(c)	The increase was primarily due to increased returns on capital investments.

Energy Purchases

Energy purchases decreased $27 million primarily due to lower PLR prices of $18 million and lower PLR volumes of $14 million, partially offset by higher transmission enhancement expenses of $6 million.

Other Operation and Maintenance

The increase (decrease) in other operation and maintenance was due to:



	Three Months
Storm costs	$	(16	)
Act 129	(3		)
Bad debts	(2		)
Canceled projects	6
Other	2
Total	$	(13	)

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~~Operating Revenues~~

~~The increase (decrease) in operating revenues for the periods ended September 30, 2019 compared with 2018 was due to:~~

Three Months Nine Months
Distribution price (a) $ 18
$ 20
Distribution volume 1
(3 )
PLR (b) 6
11
Transmission Formula Rate (c) 17
29
TCJA refund (d) 1
(6 )
Other (1 ) 1
Total $ 42
$ 52


~~(a)~~	~~Distribution price variances were primarily due to reconcilable cost recovery mechanisms approved by the PUC.~~


~~(b)~~	The increase for the nine months ended September 30, 2019 was primarily due to higher energy volumes partially offset by lower energy prices and lower transmission enhancement expenses as described below.


~~(c)~~	The increase for the three months ended September 30, 2019 was primarily due to increased returns on capital investments. The increase for the nine months ended September 30, 2019 was primarily due to $60 million of increased returns on capital investments partially offset by a $27 million unfavorable impact of the TCJA which reduced the revenue requirement that went into effect June 1, 2018.

~~(d)~~

Represents the estimated income tax savings owed to or already returned to distribution customers related to the reduced U.S. federal corporate income taxes as a result of the TCJA. The TCJA customer refund for the period January through June 2018 was recorded as a regulatory liability during the second quarter of 2018 and the negative surcharge rate for distribution customers went into effect July 1, 2018, based on the PUC Order.

~~Energy Purchases~~

Energy purchases increased $10 million for the nine months ended September 30, 2019 compared with 2018, primarily due to higher PLR volumes of $28 million, partially offset by lower PLR prices of $12 million and lower transmission enhancement expenses of $8 million.

~~Other Operation and Maintenance~~

~~The decrease in other operation and maintenance for the periods ended September 30, 2019 compared with 2018 was due to:~~

Three Months Nine Months
Storm costs $ (4 ) $ (5 )
Vegetation management 4
7
Support costs 2
(4 )
Act 129 4
3
Act 129 Smart Meter Program —
(3 )
Contractor-related expenses (3 ) 3
Other 7
(3 )
Total $ 10
$ (2 )

~~Depreciation~~

Depreciation increased $10 million and $28 million for the three and nine months ended September 30, 2019 compared with 2018, primarily due to additional assets placed into service, related to the ongoing efforts to ensure the reliability of the delivery system and the replacement of aging infrastructure as well as the roll-out of the Act 129 Smart Meter program, net of retirements.

~~Interest Expense~~

Interest expense increased $9 million for the nine months ended September 30, 2019 compared with 2018, primarily due to the June 2018 issuance of $400 million of 4.15% First Mortgage Bonds due 2048 and the September 2019 issuance of $400 million of 3.00% First Mortgage Bonds due 2049.

~~Table of Contents~~

~~Income Taxes~~

~~The increase (decrease) in income taxes for the periods ended September 30, 2019 compared with 2018 was due to:~~

Three Months Nine Months
Change in pre-tax income $ 4
$ 2
Other 1
1
Total $ 5
$ 3

~~Earnings~~

Three Months Ended Nine Months Ended
September 30, September 30,
2019 2018 2019 2018
Net Income $ 118
$ 111
$ 333
$ 334
Special Item, gain (loss), after-tax (a) —
(5 ) —
(5 )


~~(a)~~	In June 2018, PPL EU Services' IT department announced an internal reorganization which was substantially completed in the third quarter of 2018. As a result, $5 million of after-tax costs, which includes separation benefits as well as outside services for strategic consulting to establish the new IT organization, were incurred.

Earnings increased for the three month period in 2019 compared with 2018, driven primarily by returns on additional capital investments in transmission primarily offset by higher operation and maintenance expense.

Earnings decreased for the nine month period in 2019 compared with 2018, driven primarily by year-over-year differences in the impact of reduced income taxes in rates due to U.S. tax reform, higher depreciation expense and higher interest expense, offset by returns on additional capital investments in transmission.

The table below quantifies the changes in the components of Net Income between these periods, which reflect amounts classified as Pennsylvania Adjusted Gross Margins and the item that management considers special on separate lines and not in their respective Statement of Income line items.

Three Months Nine Months
Pennsylvania Adjusted Gross Margins $ 24
$ 30
Other operation and maintenance (10 ) (5 )
Depreciation (6 ) (18 )
Taxes, other than income —
(1 )
Other Income (Expense) - net (1 ) (2 )
Interest Expense (2 ) (9 )
Income Taxes (3 ) (1 )
Special Item, after tax (a) 5
5
Net Income $ 7
$ (1 )

~~(a) See PPL's "Results of Operations - Segment Earnings - Pennsylvania Regulated Segment" for details of the special item.~~

~~Adjusted Gross Margins~~

"Adjusted Gross Margins" is a non-GAAP financial performance measure that management utilizes as an indicator of the performance of its business. See PPL's "Results of Operations - Adjusted Gross Margins" for information on why management believes this measure is useful and for explanations of the underlying drivers of the changes between periods. Within PPL's discussion, PPL Electric's Adjusted Gross Margins are referred to as "Pennsylvania Adjusted Gross Margins."

The following tables contain the components from the Statements of Income that are included in this non-GAAP financial measure and a reconciliation to "Operating Income" for the periods ended September 30.

~~Table of Contents~~

2019 Three Months 2018 Three Months

Adjusted Gross
Margins
Other (a)
Operating
Income (b)

Adjusted Gross
Margins
Other (a)
Operating
Income (b)
Operating Revenues $ 590
$ —
$ 590
$ 548
$ —
$ 548
Operating Expenses
Energy purchases 132
—
132
127
—
127
Other operation and maintenance 30
107
137
23
104
127
Depreciation 14
85
99
10
79
89
Taxes, other than income 27
2
29
25
2
27
Total Operating Expenses 203
194
397
185
185
370
Total $ 387
$ (194 ) $ 193
$ 363
$ (185 ) $ 178

2019 Nine Months 2018 Nine Months

Adjusted Gross
Margins
Other (a)
Operating
Income (b)

Adjusted Gross
Margins
Other (a)
Operating
Income (b)
Operating Revenues $ 1,756
$ —
$ 1,756
$ 1,704
$ —
$ 1,704
Operating Expenses
Energy purchases 413
—
413
403
—
403
Other operation and maintenance 92
325
417
92
327
419
Depreciation 36
254
290
26
236
262
Taxes, other than income 79
5
84
77
4
81
Total Operating Expenses 620
584
1,204
598
567
1,165
Total $ 1,136
$ (584 ) $ 552
$ 1,106
$ (567 ) $ 539


~~(a)~~	~~Represents amounts excluded from Adjusted Gross Margins.~~


~~(b)~~	~~As reported on the Statements of Income.~~

LKE: Statement of Income Analysis ~~Earnings and Adjusted Gross Margins~~

Statement of Income Analysis

Net income for the ~~periods~~period ended ~~September 30~~March 31 includes the following results.


	Three Months							Nine Months								Three Months
	2019		2018		$ Change			2019		2018			$ Change			2020		2019		$ Change
Operating Revenues	$	844	$	802	$	42		$	2,421	$	2,417		$	4		$	825	$	845	$	(20	)
Operating Expenses
Operation
Fuel	194		206		(12		)	556		609			(53		)	163		194		(31		)
Energy purchases	19		22		(3		)	125		135			(10		)	57		79		(22		)
Other operation and maintenance	205		216		(11		)	627		632			(5		)	204		214		(10		)
Depreciation	144		119		25			402		354			48			149		123		26
Taxes, other than income	19		18		1			55		53			2			18		18		—
Total Operating Expenses	581		581		—			1,765		1,783			(18		)	591		628		(37		)
Other Income (Expense) - net	2		—		2			2		(2		)	4
Interest Expense	57		52		5			169		154			15			58		54		4
Interest Expense with Affiliate	7		7		—			23		18			5			7		7		—
Income Taxes	43		32		11			78		102			(24		)	34		32		2
Net Income	$	158	$	130	$	28		$	388	$	358		$	30		$	135	$	124	$	11

Operating Revenues

The increase (decrease) in operating revenues ~~for the periods ended September 30, 2019 compared with 2018~~ was due to:

~~Table of Contents~~


	Three Months			Nine Months			Three Months
Higher retail rates (a)	$	42		$	77
Retail rates (a)							$	49
ECR(b)	21			40			19
Fuel and other energy purchase prices	(7		)	(16		)
Fuel and other energy prices (c)							(21		)
Municipal supply ~~(b)~~(d)	(22		)	(37		)	(22		)
Volumes ~~(c)~~(e)	9			(65		)	(38		)
Other	(1		)	5			(7		)
Total	$	42		$	4		$	(20	)


(a)	The ~~higher retail rates were~~increase was primarily due to higher base rates, inclusive of the termination of the TCJA bill credit mechanism, effective May 1, 2019.


(b)	The ~~decreases were~~increase was primarily due to higher recoverable depreciation expense as a result of higher depreciation rates effective May 1, 2019.


(c)	The decrease was primarily due to lower recoveries of fuel and energy purchases due to lower commodity costs.


(d)	The decrease was primarily due to the termination of eight supply contracts with Kentucky municipalities on April 30, 2019.


~~(c)~~(e)	The decrease ~~for the nine months ended September 30, 2019~~ was primarily due to weather.

Fuel

~~Fuel~~Energy Purchases

Energy purchases decreased ~~$53~~$22 million ~~for the~~ ~~nine months endedSeptember 30, 2019~~ ~~compared with~~ ~~2018~~, primarily due to a ~~$22~~$14 million decrease in commodity costs and a ~~$21~~$6 million decrease in gas volumes driven by ~~weather and a $14 million decrease in volumes driven by the termination of eight supply contracts with Kentucky municipalities on April 30, 2019.~~weather.

Other Operation and Maintenance

The increase (decrease) in other operation and maintenance ~~for the periods ended September 30, 2019 compared with 2018~~ was due to:

Table of Contents

Three Months Nine Months
DSM program costs $ (4 ) $ (11 )
Plant operations and maintenance (7 ) (9 )
Storm costs (9 ) (8 )
Administrative and general 2
2
Vegetation management 2
3
Gas distribution maintenance and compliance 2
6
Transmission credits 3
10
Other —
2
Total $ (11 ) $ (5 )



	Three Months
Administrative and general	$	(5	)
Plant operations and maintenance	(3		)
Other	(2		)
Total	$	(10	)

Depreciation

Depreciation increased ~~$25~~$26 million ~~for the three months ended September 30, 2019 compared with 2018, primarily due to higher depreciation rates effective May 1, 2019.~~

~~Depreciation increased $48 million for the nine months ended September 30, 2019 compared with 2018,~~ primarily due to a ~~$33~~$19 million increase related to higher depreciation rates effective May 1, 2019 and an ~~$11~~$6 million increase related to additional assets placed into service, net of retirements.

~~Table of Contents~~

~~Income Taxes~~

~~The increase (decrease) in income taxes for the periods ended September 30, 2019 compared with 2018 was due to:~~

Three Months Nine Months
Change in pre-tax income $ 10
$ 1
Amortization of excess deferred income tax (2 ) (3 )
Kentucky state tax reform (a) —
(9 )
Kentucky recycling credit, net of federal income tax expense (b) —
(20 )
Valuation allowance adjustments (b) —
3
Other 3
4
Total $ 11
$ (24 )


~~(a)~~	During the second quarter of 2018, LKE recorded deferred income tax expense, primarily associated with LKE's non-regulated entities, due to the Kentucky corporate income tax rate reduction from 6% to 5%, as enacted by HB 487, effective January 1, 2018.

~~(b)~~

During the second quarter of 2019, LKE recorded a deferred income tax benefit associated with two projects placed into service that prepare a generation waste material for reuse and, as a result, qualify for a Kentucky recycling credit. The applicable credit provides tax benefits for a portion of the equipment costs for major recycling projects in Kentucky, with the benefit recognized during the period in which the assets are placed into service. A portion of this amount has been reserved due to insufficient Kentucky taxable income projected at LKE. During the third quarter of 2019, LKE filed the Kentucky recycling credit application with the Kentucky Department of Revenue and expects a ruling in the fourth quarter of 2019.

~~Earnings~~

Three Months Ended Nine Months Ended
September 30, September 30,
2019 2018 2019 2018
Net Income $ 158
$ 130
$ 388
$ 358
Special items, gains (losses), after-tax —
2
—
(7 )

Excluding special items, earnings increased for the three month period in 2019 compared with 2018, primarily due to higher retail rates approved by the KPSC, inclusive of the termination of the TCJA bill credit mechanism, effective May 1, 2019, higher sales volumes primarily driven by weather and lower other operation and maintenance expense. This was partially offset by lower municipal supply revenues primarily due to the termination of eight supply contracts with Kentucky municipalities on April 30, 2019, higher depreciation expense and higher income taxes.

Excluding special items, earnings increased for the nine month period in 2019 compared with 2018, primarily due to higher retail rates approved by the KPSC, inclusive of the termination of the TCJA bill credit mechanism, effective May 1, 2019, lower other operation and maintenance expense and lower income taxes. This was partially offset by lower municipal supply revenues primarily due to the termination of eight supply contracts with Kentucky municipalities, lower sales volumes primarily driven by weather, higher depreciation expense and higher interest expense.

The table below quantifies the changes in the components of Net Income between these periods, which reflect amounts classified as Adjusted Gross Margins and the items that management considers special on separate lines and not in their respective Statement of Income line items.

Three Months Nine Months
Adjusted Gross Margins $ 44
$ 42
Other operation and maintenance 10
1
Depreciation (10 ) (19 )
Taxes, other than income (2 ) (2 )
Other Income (Expense) - net 2
4
Interest Expense (5 ) (20 )
Income Taxes (9 ) 17
Special items, gains (losses), after-tax (a) (2 ) 7
Net Income $ 28
$ 30


~~(a)~~	~~See PPL's "Results of Operations - Segment Earnings - Kentucky Regulated Segment" for details of the special item.~~

~~Table of Contents~~

~~Adjusted Gross Margins~~

"Adjusted Gross Margins" is a non-GAAP financial performance measure that management utilizes as an indicator of the performance of its business. See PPL's "Results of Operations - Adjusted Gross Margins" for an explanation of why management believes this measure is useful and the factors underlying changes between periods. Within PPL's discussion, LKE's Adjusted Gross Margins are referred to as "Kentucky Adjusted Gross Margins."

2019 Three Months 2018 Three Months
Adjusted Gross Margins Other (a) Operating
Income (b) Adjusted Gross Margins Other (a) Operating
Income (b)
Operating Revenues $ 844
$ —
$ 844
$ 802
$ —
$ 802
Operating Expenses
Fuel 194
—
194
206
—
206
Energy purchases 19
—
19
22
—
22
Other operation and maintenance 25
180
205
26
190
216
Depreciation 33
111
144
18
101
119
Taxes, other than income 1
18
19
2
16
18
Total Operating Expenses 272
309
581
274
307
581
Total $ 572
$ (309 ) $ 263
$ 528
$ (307 ) $ 221

2019 Nine Months 2018 Nine Months
Adjusted Gross Margins Other (a) Operating
Income (b) Adjusted Gross Margins Other (a) Operating
Income (b)
Operating Revenues $ 2,421
$ —
$ 2,421
$ 2,417
$ —
$ 2,417
Operating Expenses
Fuel 556
—
556
609
—
609
Energy purchases 125
—
125
135
—
135
Other operation and maintenance 70
557
627
74
558
632
Depreciation 81
321
402
52
302
354
Taxes, other than income 3
52
55
3
50
53
Total Operating Expenses 835
930
1,765
873
910
1,783
Total $ 1,586
$ (930 ) $ 656
$ 1,544
$ (910 ) $ 634


~~(a)~~	~~Represents amounts excluded from Adjusted Gross Margins.~~


~~(b)~~	~~As reported on the Statements of Income.~~

~~Table of Contents~~

LG&E: Statement of Income Analysis ~~Earnings and Adjusted Gross Margins~~

Statement of Income Analysis

Net income for the ~~periods~~period ended ~~September 30~~March 31 includes the following results.


	Three Months								Nine Months									Three Months
	2019		2018			$ Change			2019			2018			$ Change			2020			2019		$ Change
Operating Revenues
Retail and wholesale	$	380	$	357		$	23		$	1,105		$	1,095		$	10		$	393		$	397	$	(4	)
Electric revenue from affiliate	2		5			(3		)	21			21			—			14			13		1
Total Operating Revenues	382		362			20			1,126			1,116			10			407			410		(3		)
Operating Expenses
Operation
Fuel	79		83			(4		)	226			234			(8		)	74			78		(4		)
Energy purchases	14		17			(3		)	110			121			(11		)	52			74		(22		)
Energy purchases from affiliate	2		2			—			6			10			(4		)	—			2		(2		)
Other operation and maintenance	92		95			(3		)	282			277			5			92			94		(2		)
Depreciation	61		49			12			168			146			22			64			51		13
Taxes, other than income	10		9			1			29			27			2			10			9		1
Total Operating Expenses	258		255			3			821			815			6			292			308		(16		)
Other Income (Expense) - net	—		(3		)	3			(1		)	(5		)	4			(1		)	—		(1		)
Interest Expense	22		20			2			65			57			8			22			21		1
Income Taxes	22		18			4			51			51			—			19			17		2
Net Income	$	80	$	66		$	14		$	188		$	188		$	—		$	73		$	64	$	9

Operating Revenues

The increase (decrease) in operating revenues ~~for the periods ended September 30, 2019 compared with 2018~~ was due to:


	Three Months			Nine Months			Three Months
Higher retail rates (a)	$	15		$	29
Retail rates (a)							$	20
ECR(b)	8			17			8
Fuel and other energy purchase prices	(3		)	(2		)
Fuel and other energy prices (c)							(12		)
Volumes ~~(b)~~(d)	1			(35		)	(18		)
Other	(1		)	1			(1		)
Total	$	20		$	10		$	(3	)


(a)	The ~~higher retail rates were~~increase was primarily due to higher base rates, inclusive of the termination of the TCJA bill credit mechanism, effective May 1, 2019.


(b)	~~For the nine months ended September 30, 2019, the~~The increase was primarily due to higher recoverable depreciation expense as a result of higher depreciation rates effective May 1, 2019.


(c)	The decrease was primarily due to lower recoveries of fuel and energy purchases due to lower commodity costs.


(d)	The decrease was primarily due to weather.

~~Fuel~~

~~Fuel decreased $4 million for the three months ended September 30, 2019 compared with 2018, primarily due to a decrease in commodity costs.~~

~~Energy Purchases~~

Energy purchases decreased $11 million for the nine months ended September 30, 2019 compared with 2018, primarily due to a $5 million decrease in commodity costs and a $4 million decrease in volumes due to the expiration of a capacity purchase tolling agreement.

~~Depreciation~~

~~Depreciation increased $12 million for the three months ended September 30, 2019 compared with 2018, primarily due to higher depreciation rates effective May 1, 2019.~~

Table of Contents

~~Depreciation increased $22~~Fuel

Fuel decreased $4 million ~~for the nine months ended September 30, 2019 compared with 2018,~~ primarily due to a ~~$16~~$3 decrease in commodity costs and a $1 decrease in volumes driven by weather.

Energy Purchases

Energy purchases decreased $22 million primarily due to a $14 million decrease in commodity costs and a $6 million decrease in gas volumes driven by weather.

Depreciation

Depreciation increased $13 million primarily due to a $9 million increase related to higher depreciation rates effective May 1, 2019 and a $6$4 million increase related to additional assets placed into service, net of retirements.

~~Income Taxes~~

~~Income taxes increased $4 million for the three months ended September 30, 2019 compared with 2018 primarily due to higher pre-tax income.~~

~~Earnings~~

Three Months Ended Nine Months Ended
September 30, September 30,
2019 2018 2019 2018
Net Income $ 80
$ 66
$ 188
$ 188
Special items, gains (losses), after-tax (a) —
—
—
—


~~(a)~~	~~There are no items management considers special for the periods presented.~~

Earnings are comparable for the nine month period in 2019 compared with 2018, primarily due to higher retail rates approved by the KPSC, inclusive of the termination of the TCJA bill credit mechanism, effective May 1, 2019 offset by lower sales volumes primarily driven by weather, higher other operation and maintenance expense, higher depreciation expense and higher interest expense.

The table below quantifies the changes in the components of Net Income between these periods, which reflect amounts classified as Adjusted Gross Margins on a separate line and not in their respective Statement of Income line items.

Three Months Nine Months
Adjusted Gross Margins $ 22
$ 23
Other operation and maintenance 2
(8 )
Depreciation (4 ) (8 )
Taxes, other than income (3 ) (3 )
Other Income (Expense) - net 3
4
Interest Expense (2 ) (8 )
Income Taxes (4 ) —
Net Income $ 14
$ —

~~Adjusted Gross Margins~~

"Adjusted Gross Margins" is a non-GAAP financial performance measure that management utilizes as an indicator of the performance of its business. See PPL's "Results of Operations - Adjusted Gross Margins" for an explanation of why management believes this measure is useful and the factors underlying changes between periods. Within PPL's discussion, LG&E's Adjusted Gross Margins are included in "Kentucky Adjusted Gross Margins."

~~Table of Contents~~

2019 Three Months 2018 Three Months
Adjusted Gross Margins Other (a) Operating Income (b) Adjusted Gross Margins Other (a) Operating Income (b)
Operating Revenues $ 382
$ —
$ 382
$ 362
$ —
$ 362
Operating Expenses
Fuel 79
—
79
83
—
83
Energy purchases, including affiliate 16
—
16
19
—
19
Other operation and maintenance 9
83
92
10
85
95
Depreciation 16
45
61
8
41
49
Taxes, other than income —
10
10
2
7
9
Total Operating Expenses 120
138
258
122
133
255
Total $ 262
$ (138 ) $ 124
$ 240
$ (133 ) $ 107

2019 Nine Months 2018 Nine Months
Adjusted Gross Margins Other (a) Operating Income (b) Adjusted Gross Margins Other (a) Operating Income (b)
Operating Revenues $ 1,126
$ —
$ 1,126
$ 1,116
$ —
$ 1,116
Operating Expenses
Fuel 226
—
226
234
—
234
Energy purchases, including affiliate 116
—
116
131
—
131
Other operation and maintenance 26
256
282
29
248
277
Depreciation 37
131
168
23
123
146
Taxes, other than income 1
28
29
2
25
27
Total Operating Expenses 406
415
821
419
396
815
Total $ 720
$ (415 ) $ 305
$ 697
$ (396 ) $ 301


~~(a)~~	~~Represents amounts excluded from Adjusted Gross Margins.~~


~~(b)~~	~~As reported on the Statements of Income.~~

~~Table of Contents~~

KU: Statement of Income Analysis ~~Earnings and Adjusted Gross Margins~~

Statement of Income Analysis

Net income for the ~~periods~~period ended ~~September 30~~March 31 includes the following results.


	Three Months							Nine Months							Three Months
	2019		2018		$ Change			2019		2018		$ Change			2020		2019		$ Change
Operating Revenues
Retail and wholesale	$	464	$	445	$	19		$	1,316	$	1,322	$	(6	)	$	432	$	448	$	(16	)
Electric revenue from affiliate	2		2		—			6		10		(4		)	—		2		(2		)
Total Operating Revenues	466		447		19			1,322		1,332		(10		)	432		450		(18		)
Operating Expenses
Operation
Fuel	115		123		(8		)	330		375		(45		)	89		116		(27		)
Energy purchases	5		5		—			15		14		1			5		5		—
Energy purchases from affiliate	2		5		(3		)	21		21		—			14		13		1
Other operation and maintenance	107		114		(7		)	320		331		(11		)	104		108		(4		)
Depreciation	83		70		13			233		208		25			84		72		12
Taxes, other than income	9		9		—			26		26		—			9		9		—
Total Operating Expenses	321		326		(5		)	945		975		(30		)	305		323		(18		)
Other Income (Expense) - net	4		1		3			4		1		3			1		2		(1		)
Interest Expense	28		24		4			82		74		8			28		26		2
Income Taxes	26		21		5			62		59		3			20		22		(2		)
Net Income	$	95	$	77	$	18		$	237	$	225	$	12		$	80	$	81	$	(1	)

Operating Revenues

The increase (decrease) in operating revenues ~~for the periods ended September 30, 2019 compared with 2018~~ was due to:


	Three Months			Nine Months			Three Months
Municipal supply (a)	(22		)	(37		)	$	(22	)
Volumes (b)	7			(29		)	(20		)
Fuel and other energy purchase prices	(4		)	(16		)
Fuel and other energy prices (c)							(9		)
ECR(d)	13			23			11
Higher Retail Rates (c)	27			48
Retail rates (e)							29
Other	(2		)	1			(7		)
Total	$	19		$	(10	)	$	(18	)


(a)	The ~~decreases were~~decrease was primarily due to the termination of eight supply contracts with Kentucky municipalities on April 30, 2019.


(b)	~~For the nine months ended September 30, 2019, the~~The decrease was primarily due to weather.


(c)	The decrease was primarily due to lower recoveries of fuel and energy purchases due to lower commodity costs.


(d)	The increase was primarily due to higher ~~retail~~recoverable depreciation expense as a result of higher depreciation rates ~~were~~effective May 1, 2019.

Table of Contents


(e)	The increase was due to higher base rates, inclusive of the termination of the TCJA bill credit mechanism, effective May 1, 2019.

Fuel

Fuel decreased $8$27 million ~~for the three months ended September 30, 2019 compared with 2018,~~ primarily due to a $12 million decrease in volumes driven by weather, an $8 million decrease in volumes driven by the termination of eight supply contracts with Kentucky municipalities on April 30, 2019 and a $6$7 million decrease in ~~commodity costs, partially offset by a $5 million increase in volumes primarily driven by weather.~~

Fuel decreased $45 million for the nine months ended September 30, 2019 compared with 2018, primarily due to a $17 million decrease in volumes driven by weather, a $16 million decrease in commodity costs and a $14 million decrease in volumes driven by the termination of eight supply contracts with Kentucky municipalities on April 30, 2019.commodity.

Other Operation and Maintenance

The increase (decrease) in other operation and maintenance ~~for the periods ended September 30, 2019 compared with 2018~~ was due to:

~~Table of Contents~~


	Three Months			Nine Months			Three Months
Plant operations and maintenance	$	(6	)	$	(10	)	$	(2	)
DSM program costs	(2		)	(5		)
Storm costs	(5		)	(5		)
Transmission credits	2			7
Administrative and general							(1		)
Other	4			2			(1		)
Total	$	(7	)	$	(11	)	$	(4	)

Depreciation

Depreciation increased ~~$13~~$12 million ~~for the three months ended September 30, 2019 compared with 2018, primarily due to higher depreciation rates effective May 1, 2019.~~

~~Depreciation increased $25 million for the~~ ~~nine months ended~~ ~~September 30, 2019 compared with 2018,~~ primarily due to a ~~$17~~$10 million increase related to higher depreciation rates effective May 1, 2019 and a $5$2 million increase related to additional assets placed into service, net of retirements.

~~Income Taxes~~

~~Income taxes increased $5 million for the three months ended September 30, 2019 compared with 2018 primarily due to higher pre-tax income.~~

~~Earnings~~

Three Months Ended Nine Months Ended
September 30, September 30,
2019 2018 2019 2018
Net Income $ 95
$ 77
$ 237
$ 225
Special items, gains (losses), after-tax (a) —
—
—
—


~~(a)~~	~~There are no items management considers special for the periods presented.~~

Earnings increased for the three month period in 2019 compared with 2018, primarily due to higher retail rates approved by the KPSC, inclusive of the termination of the TCJA bill credit mechanism, effective May 1, 2019, higher sales volumes primarily driven by weather and lower other operation and maintenance expense, partially offset by lower municipal supply revenues primarily due to the termination of eight supply contracts with Kentucky municipalities, higher depreciation expense and higher income taxes.

Earnings increased for the nine month period in 2019 compared with 2018, primarily due to higher retail rates approved by the KPSC, inclusive of the termination of the TCJA bill credit mechanism, effective May 1, 2019, and lower other operation and maintenance expense, partially offset by lower municipal supply revenues primarily due to the termination of eight supply contracts with Kentucky municipalities, lower sales volumes primarily driven by weather, higher depreciation expense and higher interest expense.

Three Months Nine Months
Adjusted Gross Margins $ 22
$ 19
Other operation and maintenance 7
10
Depreciation (6 ) (10 )
Taxes, other than income 1
1
Other Income (Expense) - net 3
3
Interest Expense (4 ) (8 )
Income Taxes (5 ) (3 )
Net Income $ 18
$ 12

~~Table of Contents~~

~~Adjusted Gross Margins~~

"Adjusted Gross Margins" is a non-GAAP financial performance measure that management utilizes as an indicator of the performance of its business. See PPL's "Results of Operations - Adjusted Gross Margins" for an explanation of why management believes this measure is useful and the factors underlying changes between periods. Within PPL's discussion, KU's Adjusted Gross Margins are included in "Kentucky Adjusted Gross Margins."

2019 Three Months 2018 Three Months
Adjusted Gross Margins Other (a) Operating
Income (b) Adjusted Gross Margins Other (a) Operating
Income (b)
Operating Revenues $ 466
$ —
$ 466
$ 447
$ —
$ 447
Operating Expenses
Fuel 115
—
115
123
—
123
Energy purchases, including affiliate 7
—
7
10
—
10
Other operation and maintenance 16
91
107
16
98
114
Depreciation 17
66
83
10
60
70
Taxes, other than income 1
8
9
—
9
9
Total Operating Expenses 156
165
321
159
167
326
Total $ 310
$ (165 ) $ 145
$ 288
$ (167 ) $ 121

2019 Nine Months 2018 Nine Months
Adjusted Gross Margins Other (a) Operating
Income (b) Adjusted Gross Margins Other (a) Operating
Income (b)
Operating Revenues $ 1,322
$ —
$ 1,322
$ 1,332
$ —
$ 1,332
Operating Expenses
Fuel 330
—
330
375
—
375
Energy purchases, including affiliate 36
—
36
35
—
35
Other operation and maintenance 44
276
320
45
286
331
Depreciation 44
189
233
29
179
208
Taxes, other than income 2
24
26
1
25
26
Total Operating Expenses 456
489
945
485
490
975
Total $ 866
$ (489 ) $ 377
$ 847
$ (490 ) $ 357


~~(a)~~	~~Represents amounts excluded from Adjusted Gross Margins.~~


~~(b)~~	~~As reported on the Statements of Income.~~

~~Table of Contents~~

Financial Condition

The remainder of this Item 2 in this Form 10-Q is presented on a combined basis, providing information, as applicable, for all Registrants.

Liquidity and Capital Resources

(All Registrants)

The Registrants had the following at:


	PPL (a)		PPL Electric		LKE		LG&E		KU		PPL (a)		PPL Electric		LKE		LG&E		KU
September 30, 2019
March 31, 2020
Cash and cash equivalents	$	670	$	27	$	30	$	12	$	18	$	915	$	33	$	47	$	7	$	40
Short-term debt	1,387		—		101		99		2		1,696		85		303		159		144
Long-term debt due within one year	—		—		—		—		—		1,170		—		975		—		500
Notes payable with affiliates			—		129		—		—				—		242		21		—

December 31, 2018
December 31, 2019
Cash and cash equivalents	$	621	$	267	$	24	$	10	$	14	$	815	$	262	$	27	$	15	$	12
Short-term debt	1,430		—		514		279		235		1,151		—		388		238		150
Long-term debt due within one year	530		—		530		434		96		1,172		—		975		—		500
Notes payable with affiliates			—		113		—		—				—		150		—		—


(a)	At ~~September 30, 2019, $279~~March 31, 2020, $174 million of cash and cash equivalents were denominated in GBP. If these amounts would be remitted as dividends, PPL would not anticipate an incremental U.S. tax cost. See Note 6 to the Financial Statements in PPL's ~~2018~~2019 Form 10-K for additional information on undistributed earnings of WPD.

Net cash provided by (used in) operating, investing and financing activities for the ~~nine~~three month periods ended ~~September 30,~~March 31, and the changes between periods, were as follows.

Table of Contents

PPL PPL Electric LKE LG&E KU
2019
Operating activities $ 1,888
$ 609
$ 813
$ 417
$ 471
Investing activities (2,194 ) (1,361 ) (761 ) (323 ) (436 )
Financing activities 363
512
(46 ) (92 ) (31 )
2018
Operating activities $ 2,210
$ 650
$ 787
$ 410
$ 485
Investing activities (2,466 ) (837 ) (825 ) (420 ) (404 )
Financing activities 618
552
37
6
(78 )
Change - Cash Provided (Used)
Operating activities $ (322 ) $ (41 ) $ 26
$ 7
$ (14 )
Investing activities 272
(524 ) 64
97
(32 )
Financing activities (255 ) (40 ) (83 ) (98 ) 47



	PPL			PPL Electric			LKE			LG&E			KU
2020
Operating activities	$	692		$	132		$	320		$	171		$	193
Investing activities	(833		)	(281		)	(255		)	(117		)	(159		)
Financing activities	240			(80		)	(45		)	(62		)	(6		)
2019
Operating activities	$	474		$	81		$	270		$	157		$	174
Investing activities	(722		)	(264		)	(278		)	(117		)	(161		)
Financing activities	142			(61		)	6			(41		)	(14		)
Change - Cash Provided (Used)
Operating activities	$	218		$	51		$	50		$	14		$	19
Investing activities	(111		)	(17		)	23			—			2
Financing activities	98			(19		)	(51		)	(21		)	8

Operating Activities

The components of the change in cash provided by (used in) operating activities for the ~~nine~~three months ended ~~September 30, 2019~~March 31, 2020 compared with ~~2018~~2019 were as follows.

~~Table of Contents~~


	PPL			PPL Electric			LKE			LG&E			KU			PPL			PPL Electric			LKE			LG&E			KU
Change - Cash Provided (Used)
Net income	$	(30	)	$	(1	)	$	30		$	—		$	12		$	88		$	(3	)	$	11		$	9		$	(1	)
Non-cash components	138			19			59			24			36			(44		)	29			18			(3		)	2
Working capital	(282		)	(68		)	(140		)	(74		)	(97		)	98			14			7			12			8
Defined benefit plan funding	3			7			92			53			50			2			—			(2		)	(4		)	(1		)
Other operating activities	(151		)	2			(15		)	4			(15		)	74			11			16			—			11
Total	$	(322	)	$	(41	)	$	26		$	7		$	(14	)	$	218		$	51		$	50		$	14		$	19

(PPL)

PPL's cash provided by operating activities in ~~2019 decreased $322~~2020 increased $218 million compared with ~~2018.~~2019.

Net income ~~decreased $30~~increased $88 million between the periods and included ~~an increase~~a decrease in non-cash charges of ~~$138~~$44 million. The ~~increase~~decrease in non-cash charges was primarily due to ~~a decrease~~an increase in unrealized gains on hedging activities, ~~and~~partially offset by an increase in depreciation expense (primarily due to higher depreciation rates and additional assets placed into service, ~~related to the ongoing efforts to ensure the reliability of the delivery system and the replacement of aging infrastructure,~~ net of ~~retirements~~retirements), an increase in deferred income taxes (due to book versus tax plant timing differences and ~~higher depreciation rates), partially offset by an increase~~Federal net operating losses) and a decrease in the U.K. net periodic defined benefit credits (primarily due to ~~lower~~higher levels of unrecognized losses being amortized).

The ~~$282~~$98 million ~~decrease~~increase in cash from changes in working capital was primarily due to an increase in net regulatory assets and liabilities (primarily due to the impact of the TCJA and timing of rate recovery mechanisms), an increase in unbilled revenues (primarily due to weather and higher retail rates effective May 1, 2019), a decrease in accounts payable (primarily due to timing of payments) ~~and~~, a decrease in ~~other current liabilities~~accounts receivable (primarily due to timing of ~~payments), partially offset by an increase~~receipts) and a decrease in ~~accrued interest~~unbilled revenues (primarily due ~~larger debt balances and timing of interest payments)~~to weather).

The ~~$151~~$74 million ~~decrease~~increase in cash provided by other operating activities was primarily due to the $65 million transfer of excess benefits funds, in 2018, related to the favorable private letter ruling received by PPL from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay for medical claims of active bargaining unit employees, a decreasean increase in non-current regulatory liabilities, ~~(primarily due to a $41 million TCJA liability~~an increase in ~~2018)~~accrued pension obligation and an increase in ARO expenditures.

(PPL Electric)

PPL Electric's cash provided by operating activities in ~~2019 decreased $41~~2020 increased $51 million compared with ~~2018.~~2019.

Net income decreased $1$3 million between the periods and included an increase in non-cash components of ~~$19~~$29 million. The increase in non-cash components was primarily due to a ~~$28~~$16 million increase in depreciation expense (primarily due to additional assets placed into service, related to the ongoing efforts to ensure reliability of the delivery system and the replacement of aging infrastructure as well as the roll-out of the Act 129 Smart Meter program), partially offset by a $7 million decrease in deferred income taxes (due to book versus tax plant timing differences and Federal net operating ~~losses, partially offset by~~losses) and a ~~book~~$10 million increase in other expenses (primarily due to ~~tax timing difference related to the TCJA regulatory liability)~~an increase in canceled projects).

The ~~$68~~$14 million ~~decrease~~increase in cash from changes in working capital was primarily due to ~~an increase~~a decrease in unbilled ~~revenue~~revenues (primarily due to ~~colder weather in the fourth quarter of 2017 compared with 2018), an increase~~weather) and a decrease in prepayments (primarily due to ~~an increase in the 2019~~timing of prepayments including gross ~~receipts~~

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receipt tax ~~prepayment compared to 2018~~ and ~~a 2018 state~~other income tax overpayment to be applied to the 2019 state income tax liability), an increase in net regulatory assets and liabilities (due to timing of rate recovery mechanisms and colder weather in the fourth quarter of 2018 compared with the third quarter of 2019) and in increase in Other (primarily due to timing of payments for other current liabilities and a 2018 initiative to decrease material and supply levels)prepayments), partially offset by a decrease in accounts ~~receivable~~payable (primarily due to timing of ~~receipts)~~payments).

~~Defined benefit plan funding was $7 million lower in 2019.~~

The $2$11 million increase in cash provided by other operating activities was primarily due to ~~a decrease~~an increase in ~~non-current regulatory~~other liabilities (primarily due to ~~a $41 million TCJA liability~~an increase in ~~2018), partially offset by a decrease in non-current~~accrued pension obligations and noncurrent regulatory ~~assets (due to timing of rate recovery mechanisms, amortization of storm costs incurred in the prior year and $22 million of storm costs incurred in 2018)~~liabilities).

~~Table of Contents~~

(LKE)

LKE's cash provided by operating activities in ~~2019~~2020 increased ~~$26~~$50 million compared with ~~2018.~~2019.


•	Net income increased $3011 million between the periods and included an increase in non-cash ~~charges~~components of $5918 million. The increase in non-cash ~~charges~~components was primarily driven by an increase in depreciation expense (primarily due to higher depreciation rates and additional assets placed into service, net of retirements).

The ~~decrease~~increase in cash from changes in working capital was primarily driven by an increase in ~~net regulatory assets and liabilities~~accounts payable (primarily due to ~~the impact of the TCJA and~~ timing of ~~rate recovery mechanisms)~~payments), ~~an increase in unbilled revenues (primarily due to weather and higher retail rates effective May 1, 2019) and~~ a decrease in accounts receivable (primarily due to weather) and an increase in interest payable (primarily due to higher interest rates and higher outstanding debt) partially offset by a decrease in other current liabilities (primarily due to timing of payments).


•	~~Defined benefit plan funding was~~ ~~$92 million~~ ~~lower in 2019.~~

The ~~decrease~~increase in cash ~~from LKE's~~provided by other operating activities was driven primarily ~~driven~~ by ~~an increase~~a decrease in ARO expenditures.

(LG&E)

LG&E's cash provided by operating activities in ~~2019~~2020 increased $7$14 million compared with ~~2018.~~2019.

•

Net income ~~was consistent~~increased $9 million between the periods and included ~~an increase~~a decrease in non-cash ~~charges~~components of $243 million. The ~~increase~~decrease in non-cash ~~charges~~components was primarily driven by a decrease in deferred income tax expense (primarily due to book versus tax plant timing differences) and a decrease in amortization expense (primarily due to amortization of regulatory liabilities beginning May 1, 2019), partially offset by an increase in depreciation expense (primarily due to higher depreciation rates and additional assets placed into service, net of retirements).

The ~~decrease~~increase in cash from changes in working capital was primarily driven by an increase in ~~net regulatory assets~~taxes payable (primarily due to timing of payments), an increase in interest payable (primarily due to higher interest rates and higher outstanding debt), partially offset by a decrease in other current liabilities (primarily due to ~~the impact of the TCJA and the~~ timing of ~~rate recovery mechanisms), an increase in unbilled revenues (primarily due to weather and higher retail rates effective May 1, 2019)~~payments) and a decrease in accounts payable (primarily due to timing of payments).


•	~~Defined benefit plan funding was~~ ~~$53 million~~ ~~lower in 2019.~~

(KU)

KU's cash provided by operating activities in ~~2019 decreased $14~~2020 increased $19 million compared with ~~2018.~~2019.

•

Net income ~~increased~~decreased $121 million between the periods and included an increase in non-cash charges of $362 million. The increase in non-cash ~~charges~~components was ~~primarily~~ driven by an increase in depreciation expense (primarily due to higher depreciation rates and additional assets placed into service, net of retirements), partially offset by a decrease in deferred income tax expense (primarily due to book versus tax plant timing differences).

The ~~decrease~~increase in cash from changes in working capital was primarily driven by an increase in accounts payable (primarily due to timing of payments), an increase in taxes payable (primarily due to timing of payments) and a decrease in unbilled revenues (primarily due to weather), partially offset by a decrease in other current liabilities (primarily due to timing of payments) and an increase in net regulatory assets and liabilities (primarily due to the ~~impact of the TCJA and~~ timing of rate recovery mechanisms)~~, an increase in unbilled revenues (primarily due to weather and higher retail rates effective May 1, 2019) and a decrease in accounts payable (primarily due to timing of payments)~~.

~~Defined benefit plan funding was $50 million lower in 2019.~~

The ~~decrease~~increase in cash ~~from KU's~~provided by other operating activities was driven primarily ~~driven~~ by ~~an increase~~a decrease in ARO expenditures.

Investing Activities

~~Expenditures for Property, Plant and Equipment~~ (All Registrants)

~~Investment in PP&E is the primary investing activity~~The components of the ~~Registrants. The changes~~change in cash ~~used in expenditures for PP&E~~provided by (used in) investing activities for the ~~nine~~three months ended ~~September 30, 2019~~March 31, 2020 compared with ~~2018~~2019 were as follows.

PPL PPL Electric LKE LG&E KU
Change - Cash Provided (Used)
Expenditures for PP&E $ 147
$ 20
$ 65
$ 97
$ (31 )

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	PPL			PPL Electric			LKE		LG&E		KU
Change - Cash Provided (Used)
Expenditures for PP&E	$	(97	)	$	(16	)	$	23	$	—	$	23
Purchase of investments	55			—			—		—		—
Proceeds from the sale of investments	(57		)	—			—		—		—
Notes receivable with affiliate	—			—			—		—		(21		)
Other investing activities	(12		)	—			—		—		—
Total	$	(111	)	$	(16	)	$	23	$	—	$	2

For PPL, the ~~decrease~~increase in expenditures for PP&E was due to ~~lower~~higher project expenditures at WPD and PPL Electric, ~~LKE and LG&E,~~ partially offset by ~~higher~~a decrease in project expenditures at LKE and KU. The ~~decrease~~increase in expenditures at WPD was primarily due to ~~a decrease~~an increase in expenditures to enhance system reliability and ~~a decrease~~an increase in foreign currency exchange rates. The ~~decrease~~increase in expenditures at PPL Electric was primarily due to timing differences on capital spending projects related to the ongoing efforts to improve reliability and replace aging infrastructure. The decrease in expenditures at LKE was primarily due to decreased spending for environmental water projects at LG&E and KU's Trimble County plant, LG&E's Mill Creek ~~and Trimble County plants~~plant and KU's Ghent plant, partially offset by spending on various other projects at LG&E and KU that are not individually significant.

~~Other Significant Changes in Components of Investing Activities~~ ~~(PPL Electric)~~

~~For PPL Electric, the changes in "Notes receivable with affiliates activity, net" resulted in funding of $546 million to affiliates for general corporate purposes.~~

Financing Activities

(All Registrants)

The components of the change in cash provided by (used in) financing activities for the ~~nine~~three months ended ~~September 30, 2019~~March 31, 2020 compared with ~~2018~~2019 were as follows.


	PPL			PPL Electric			LKE			LG&E			KU			PPL			PPL Electric			LKE			LG&E			KU
Change - Cash Provided (Used)
Debt issuance/retirement, net	$	940		$	(5	)	$	414		$	99		$	315
Debt issuance/retirement with affiliate, net				—			(250		)	—			—
Stock issuances/redemptions, net	(629		)	—			—			—			—			$	(2	)	$	—		$	—		$	—		$	—
Dividends	(47		)	(5		)	—			(17		)	29			(21		)	(45		)	—			1			2
Capital contributions/distributions, net	—			(29		)	74			(18		)	23			—			—			4			25			9
Issuance of term loan																200			—			—			—			—
Change in short-term debt, net	(515		)	—			(473		)	(157		)	(316		)	(79		)	25			(73		)	(69		)	(4		)
Notes payable with affiliate				—			161			—			—						—			18			21			—
Other financing activities	(4		)	(1		)	(9		)	(5		)	(4		)	—			1			—			1			1
Total	$	(255	)	$	(40	)	$	(83	)	$	(98	)	$	47		$	98		$	(19	)	$	(51	)	$	(21	)	$	8

See Note 8 to the Financial Statements in this Form 10-Q for information on ~~2019~~2020 short-term and long-term debt activity, equity transactions and PPL dividends. See Note 8 to the Financial Statements in the Registrants' ~~2018~~2019 Form 10-K for information on ~~2018~~2019 activity.

Credit Facilities

The Registrants maintain credit facilities to enhance liquidity, provide credit support and provide a backstop to commercial paper programs. Amounts borrowed under these credit facilities are reflected in "Short-term debt" on the Balance Sheets. At ~~September 30, 2019,~~March 31, 2020, the total committed borrowing capacity under credit facilities and the borrowings under these facilities were:

~~External~~

Committed
Capacity
Borrowed
Letters of
Credit
and
Commercial
Paper Issued

Unused
Capacity
PPL Capital Funding Credit Facilities $ 1,550
$ —
$ 996
$ 554
PPL Electric Credit Facility 650
—
1
649

LG&E Credit Facilities 500
—
99
401
KU Credit Facilities 400
—
2
398
Total LKE 900
—
101
799
Total U.S. Credit Facilities (a) $ 3,100
$ —
$ 1,098
$ 2,002
Total U.K. Credit Facilities (b) £ 1,055
£ 216
£ —
£ 840

Table of Contents

External



	Committed Capacity		Borrowed		Letters of Credit and Commercial Paper Issued		Unused Capacity
PPL Capital Funding Credit Facilities	$	1,700	$	825	$	180	$	695
PPL Electric Credit Facility	650		85		1		564

LG&E Credit Facilities	500		100		59		341
KU Credit Facilities	400		100		44		256
Total LKE	900		200		103		597
Total U.S. Credit Facilities (a)	$	3,250	$	1,110	$	284	$	1,856
Total U.K. Credit Facilities (b)	£	1,055	£	210	£	—	£	847


(a)	The commitments under the U.S. credit facilities are provided by a diverse bank group, with no one bank and its affiliates providing an aggregate commitment of more than the following percentages of the total committed capacity: PPL - 8%12%, PPL Electric - 6%, LKE - 7%, LG&E - 7% and KU - 7%.

(b)

The amounts borrowed at ~~September 30, 2019~~March 31, 2020 were a USD-denominated borrowing of $200 million and GBP-denominated borrowings of ~~£51~~£54 million which equated to ~~$62~~$69 million. The unused capacity reflects the USD denominated borrowing amount borrowed in GBP of ~~£164~~£154 million as of the date borrowed. At ~~September 30, 2019,~~March 31, 2020, the USD equivalent of unused capacity under the U.K. committed credit facilities was $1$1.1 billion.

The commitments under the U.K. credit facilities are provided by a diverse bank group, with no one bank providing more than 13% of the total committed capacity.

~~In September 2019, KU terminated its $198 million letter of credit facility in connection with the remarketing of variable rate debt to long-term mode bonds.~~

See Note 8 to the Financial Statements for further discussion of the Registrants' credit facilities.

Intercompany (LKE, LG&E and KU)


	Committed Capacity		Borrowed		Non-affiliate Used Capacity		Unused Capacity		Committed Capacity		Borrowed		Non-affiliate Used Capacity		Unused Capacity
LKE Credit Facility	$	375	$	129	$	—	$	246	$	375	$	242	$	—	$	133
LG&E Money Pool (a)	500		—		99		401		500		21		159		320
KU Money Pool (a)	500		—		2		498		500		—		144		356


(a)	LG&E and KU participate in an intercompany money pool agreement whereby LKE, LG&E and/or KU make available funds up to $500 million at an interest rate based on a market index of commercial paper issues. However, the FERC has issued a maximum aggregate short-term debt limit for each utility at $500 million from all covered sources.

See Note 1211 to the Financial Statements for further discussion of intercompany credit facilities.

Commercial Paper (All Registrants)

PPL, PPL Electric, LG&E and KU maintain commercial paper programs to provide an additional financing source to fund short-term liquidity needs, as necessary. Commercial paper issuances, included in "Short-term debt" on the Balance Sheets, are supported by the respective Registrant's credit facility. The following commercial paper programs were in place at ~~September 30, 2019:~~March 31, 2020:


	Capacity		Commercial Paper Issuances		Unused Capacity		Capacity		Commercial Paper Issuances		Unused Capacity
PPL Capital Funding	$	1,500	$	981	$	519	$	1,500	$	180	$	1,320
PPL Electric	650		—		650		650		—		650

LG&E	350		99		251		350		59		291
KU	350		2		348		350		44		306
Total LKE	700		101		599		700		103		597
Total PPL	$	2,850	$	1,082	$	1,768	$	2,850	$	283	$	2,567

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Long-term Debt (All Registrants)

See Note 8 to the Financial Statements for information regarding the Registrants’ long-term debt activities.

(PPL)

Equity Securities Activities

ATM

~~Table of Contents~~

component. The compensation paid to the selling agents by PPL may be up to 2% of the gross offering proceeds of the shares. There were no issuances under the ATM program for the three ~~and nine~~ months ended ~~September 30, 2019.~~March 31, 2020.

Common Stock Dividends

Rating Agency Actions

(All Registrants)

Moody's and S&P periodically review the credit ratings of the debt of the Registrants and their subsidiaries. Based on their respective independent reviews, the rating agencies may make certain ratings revisions or ratings affirmations.

A credit rating reflects an assessment by the rating agency of the creditworthiness associated with an issuer and particular securities that it issues. The credit ratings of the Registrants and their subsidiaries are based on information provided by the Registrants and other sources. The ratings of Moody's and S&P are not a recommendation to buy, sell or hold any securities of the Registrants or their subsidiaries. Such ratings may be subject to revisions or withdrawal by the agencies at any time and should be evaluated independently of each other and any other rating that may be assigned to the securities.

The credit ratings of the Registrants and their subsidiaries affect their liquidity, access to capital markets and cost of borrowing under their credit facilities. A downgrade in the Registrants' or their subsidiaries' credit ratings could result in higher borrowing costs and reduced access to capital markets. The Registrants and their subsidiaries have no credit rating triggers that would result in the reduction of access to capital markets or the acceleration of maturity dates of outstanding debt.

The rating agencies have taken the following actions related to the Registrants and their subsidiaries during ~~2019:~~2020:

(PPL)

In ~~September 2019, Moody's and S&P assigned ratings of Baa1 and A- to WPD (East Midlands) £250 million of 1.75% Senior Notes due 2031.~~

~~(PPL, LKE and LG&E)~~

~~In March 2019,~~April 2020, Moody’s and S&P assigned ratings of A1Baa2 and ABBB+ to ~~LG&E’s $400 million 4.25% First Mortgage Bonds~~PPL Capital Funding’s $1 billion 4.125% Senior Notes due ~~2049.~~2030. The bonds were issued April 1, ~~2019.~~

In March 2019, Moody’s and S&P assigned ratings of A1 and A to the County of Jefferson, Kentucky’s $128 million 1.85% Pollution Control Revenue Bonds, 2001 Series A, due 2033, previously issued on behalf of LG&E. The bonds were remarketed April 1, 2019.

In May 2019, Moody's assigned a rating of A1, and in June 2019, S&P assigned a rating of A to the County of Jefferson, Kentucky's $31 million 1.65% Series A Environmental Facilities Revenue Refunding Bonds, due 2033, previously issued on behalf of LG&E. The bonds were remarketed June 1, 2019.

In May 2019, Moody's assigned a rating of A1, and in June 2019, S&P assigned a rating of A to the County of Jefferson, Kentucky's $35 million 1.65% Series B Environmental Facilities Revenue Refunding Bonds, due 2033, previously issued on behalf of LG&E. The bonds were remarketed June 1, 2019.

In September 2019, Moody's and S&P assigned ratings of A1 and A to the County of Jefferson, Kentucky's $40 million 1.75% Pollution Control Revenue Bonds, 2005 Series A, due 2035, previously issued on behalf of LG&E.

~~(PPL, LKE and KU)~~

~~In March 2019, Moody’s assigned a rating of A1 and S&P assigned a rating of A to KU’s $300 million 4.375% First Mortgage Bonds due 2045. The bonds were issued April 1, 2019.~~

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In August 2019, Moody's assigned a rating of A1, and in September 2019, S&P assigned a rating of A to the County of Carroll, Kentucky's $96 million 1.55% Pollution Control Revenue Refunding Bonds, 2016 Series A (Kentucky Utilities Company Project), due 2042, previously issued on behalf of KU. The bonds were remarketed September 3, 2019.

~~In August 2019, Moody's assigned a rating of A1, and in September 2019, S&P lowered its rating to A to the following bonds:~~

~~County of Carroll, Kentucky��s $50 million 1.75% Environmental Facilities Revenue Bonds, 2004 Series A due 2034;~~

~~County of Carroll, Kentucky’s $54 million 1.20% Environmental Facilities Revenue Refunding Bonds, 2006 Series B due 2034;~~

~~County of Carroll, Kentucky’s $78 million 1.20% Environmental Facilities Revenue Bonds, 2006 Series B due 2032;~~

~~County of Mercer, Kentucky’s $13 million 1.30% Solid Waste Disposal Facility Revenue Bonds, 2000 Series A due 2023.~~

The bonds, previously issued on behalf of KU, were remarketed September 3, 2019. S&P and Moody’s lowered their ratings as a result of KU's termination of the letters of credit that previously provided credit enhancement for these bonds. See Note 8 to the Financial Statements for additional information.

~~(PPL and PPL Electric)~~

~~In September 2019, Moody’s and S&P assigned ratings of A1 and A to PPL Electric’s $400 million 3.00% First Mortgage Bonds due 2049.~~2020.

Ratings Triggers

(PPL, LKE, LG&E and KU)

Various derivative and non-derivative contracts, including contracts for the sale and purchase of electricity and fuel, commodity transportation and storage, interest rate and foreign currency instruments (for PPL), contain provisions that require the posting of additional collateral or permit the counterparty to terminate the contract, if PPL's, LKE's, LG&E's or KU's or their subsidiaries' credit rating, as applicable, were to fall below investment grade. See Note 1514 to the Financial Statements for a discussion of "Credit Risk-Related Contingent Features," including a discussion of the potential additional collateral requirements for PPL, LKE and LG&E for derivative contracts in a net liability position at ~~September 30, 2019.~~March 31, 2020.

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(All Registrants)

For additional information on the Registrants' liquidity and capital resources, see "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Registrants' ~~2018~~2019 Form 10-K.

Risk Management

Market Risk

(All Registrants)

See Notes 1413 and 1514 to the Financial Statements for information about the Registrants' risk management objectives, valuation techniques and accounting designations.

The forward-looking information presented below provides estimates of what may occur in the future, assuming certain adverse market conditions and model assumptions. Actual future results may differ materially from those presented. These are not precise indicators of expected future losses, but are rather only indicators of possible losses under normal market conditions at a given confidence level.

Interest Rate Risk

The Registrants and their subsidiaries issue debt to finance their operations, which exposes them to interest rate risk. The Registrants and their subsidiaries utilize various financial derivative instruments to adjust the mix of fixed and floating interest rates in their debt portfolios, adjust the duration of their debt portfolios and lock in benchmark interest rates in anticipation of future financing, when appropriate. Risk limits under the risk management program are designed to balance risk exposure to volatility in interest expense and changes in the fair value of the debt portfolios due to changes in the absolute level of interest

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rates. In addition, the interest rate risk of certain subsidiaries is potentially mitigated as a result of the existing regulatory framework or the timing of rate cases.

The following interest rate hedges were outstanding at ~~September 30, 2019.~~March 31, 2020.


	Exposure Hedged		Fair Value, Net - Asset (Liability) (a)			Effect of a 10% Adverse Movement in Rates (b)			Maturities Ranging Through	Exposure Hedged		Fair Value, Net - Asset (Liability) (a)			Effect of a 10% Adverse Movement in Rates (b)			Maturities Ranging Through
PPL
Cash flow hedges
Interest rate swaps (c)										$	134	$	(5	)	$	—		2035
Cross-currency swaps (c)	$	702	$	198		$	(69	)	2028	702		171			(70		)	2028
Economic hedges
Interest rate swaps (d)	147		(25		)	(1		)	2033	147		(29		)	—			2033
LKE
Economic hedges
Interest rate swaps (d)	147		(25		)	(1		)	2033	147		(29		)	—			2033
LG&E
Economic hedges
Interest rate swaps (d)	147		(25		)	(1		)	2033	147		(29		)	—			2033


(a)	Includes accrued interest, if applicable.


(b)	Effects of adverse movements decrease assets or increase liabilities, as applicable, which could result in an asset becoming a liability. Sensitivities represent a 10% adverse movement in interest rates, except for cross-currency swaps which also includes a 10% adverse movement in foreign currency exchange rates.


(c)	Changes in the fair value of these instruments are recorded in equity and reclassified into earnings in the same period during which the item being hedged affects earnings.


(d)	Realized changes in the fair value of such economic hedges are recoverable through regulated rates and any subsequent changes in the fair value of these derivatives are included in regulatory assets or regulatory liabilities.

The Registrants are exposed to a potential increase in interest expense and to changes in the fair value of their debt portfolios. The estimated impact of a 10% adverse movement in interest rates on interest expense at ~~September 30, 2019~~March 31, 2020 was insignificant for

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PPL, PPL Electric, LKE, LG&E and KU. The estimated impact of a 10% adverse movement in interest rates on the fair value of debt at ~~September 30, 2019~~March 31, 2020 is shown below.


	10% Adverse Movement in Rates		10% Adverse Movement in Rates
PPL	$	641	$	638
PPL Electric	198		198
LKE	198		193
LG&E	85		84
KU	104		104

Foreign Currency Risk (PPL)

PPL is exposed to foreign currency risk primarily through investments in and earnings of U.K. affiliates. Under its risk management program, PPL may enter into financial instruments to hedge certain foreign currency exposures, including translation risk of expected earnings, firm commitments, recognized assets or liabilities, anticipated transactions and net investments.

The following foreign currency hedges were outstanding at ~~September 30, 2019.~~March 31, 2020.

Exposure
Hedged

Fair Value,
Net - Asset
(Liability)

Effect of a
10%
Adverse
Movement
in Foreign
Currency
Exchange
Rates (a)

Maturities
Ranging
Through
Economic hedges (b) £ 1,004
$ 220
$ (105 ) 2020

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	Exposure Hedged		Fair Value, Net - Asset (Liability)		Effect of a 10% Adverse Movement in Foreign Currency Exchange Rates (a)			Maturities Ranging Through
Economic hedges (b)	£	686	$	190	$	(67	)	2021


(a)	Effects of adverse movements decrease assets or increase liabilities, as applicable, which could result in an asset becoming a liability.


(b)	To economically hedge the translation risk of expected earnings denominated in GBP.

(All Registrants)

Commodity Price Risk

PPL is exposed to commodity price risk through its domestic subsidiaries as described below.


•	PPL Electric is required to purchase electricity to fulfill its obligation as a PLR. Potential commodity price risk is insignificant and mitigated through its PUC-approved cost recovery mechanism and full-requirement supply agreements to serve its PLR customers which transfer the risk to energy suppliers.


•	LG&E's and KU's rates include certain mechanisms for fuel, fuel-related expenses and energy purchases. In addition, LG&E's rates include a mechanism for natural gas supply expenses. These mechanisms generally provide for timely recovery of market price fluctuations associated with these expenses.

Volumetric Risk


•	WPD is exposed to volumetric risk which is significantly mitigated as a result of the method of regulation in the U.K. Under the RIIO-ED1 price control regulations, recovery of such exposure occurs on a two year lag. See Note 1 in PPL's ~~2018~~2019 Form 10-K for additional information on revenue recognition under RIIO-ED1.


•	PPL Electric, LG&E and KU are exposed to volumetric risk on retail sales, mainly due to weather and other economic conditions for which there is limited mitigation between rate cases.

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Credit Risk (All Registrants)

See Notes 1413 and 1514 to the Financial Statements in this Form 10-Q and "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations - Financial Condition - Risk Management - Credit Risk" in the Registrants' ~~2018~~2019 Form 10-K for additional information.

Foreign Currency Translation (PPL)

The value of the British pound sterling fluctuates in relation to the U.S. dollar. Changes in this exchange rate resulted in a foreign currency translation loss of ~~$369~~$63 million for the ~~nine~~three months ended ~~September 30, 2019,~~March 31, 2020, which primarily reflected a ~~$599~~$108 million decrease to PP&E, a ~~$114~~$20 million decrease to goodwill, partially offset by a $63 million decrease to long-term debt and a ~~$16~~$2 million decrease to other net ~~assets, partially offset by a $360 million decrease to long-term debt.~~liabilities. Changes in this exchange rate resulted in a foreign currency translation ~~loss~~gain of ~~$330~~$294 million for the ~~nine~~three months ended ~~September 30, 2018,~~March 31, 2019, which primarily reflected a ~~$549~~$504 million ~~decrease~~increase to PP&E and a ~~$110~~$98 million ~~decrease~~increase to goodwill, partially offset by a ~~$319~~$304 million ~~decrease~~increase to long-term debt and a ~~$10~~$4 million ~~decrease~~increase to other net liabilities. The impact of foreign currency translation is recorded in AOCI.

Related Party Transactions (All Registrants)

The Registrants are not aware of any material ownership interests or operating responsibility by senior management in outside partnerships, including leasing transactions with variable interest entities, or other entities doing business with the Registrants. See Note 1211 to the Financial Statements for additional information on related party transactions for PPL Electric, LKE, LG&E and KU.

Acquisitions, Development and Divestitures (All Registrants)

The Registrants from time to time evaluate opportunities for potential acquisitions, divestitures and development projects. Development projects are reexamined based on market conditions and other factors to determine whether to proceed with, modify or terminate the projects. Any resulting transactions may impact future financial results.

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~~Capacity Needs(PPL, LKE, LG&E and KU)~~

As a result of environmental requirements and energy efficiency measures, KU retired two older coal-fired electricity generating units at the E.W. Brown plant in February 2019 with a combined summer rating capacity of 272 MW. Despite the retirement of these units, LG&E and KU maintain sufficient generating capacity to serve their load.

Environmental Matters

(All Registrants)

Extensive federal, state and local environmental laws and regulations are applicable to PPL's, PPL Electric's, LKE's, LG&E's and KU's air emissions, water discharges and the management of hazardous and solid waste, as well as other aspects of the Registrants' businesses. The ~~cost~~costs of compliance or alleged non-compliance cannot be predicted with certainty but could be significant. In addition, costs may increase significantly if the requirements or scope of environmental laws or regulations, or similar rules, are expanded or changed. Costs may take the form of increased capital expenditures or operating and maintenance expenses, monetary fines, penalties or other restrictions. Many of these environmental law considerations are also applicable to the operations of key suppliers, or customers, such as coal producers and industrial power users, and may impact the ~~cost~~costs for their products or their demand for the Registrants' services. Increased capital and operating costs are subject to rate recovery. PPL, PPL Electric, LKE, LG&E and KU can provide no assurances as to the ultimate outcome of future environmental or rate proceedings before regulatory authorities.

See ~~below~~"Environmental Matters" in Item 1. "Business" in the Registrants' 2019 Form 10-K for ~~further discussion of~~information about environmental laws and regulations affecting the ~~EPA's CCR Rule and~~Registrants' business. See "Legal Matters" in Note 1110 to the Financial Statements for a discussion of ~~other~~ significant environmental ~~matters including Legal Matters, NAAQS, Climate Change,~~claims. See "Financial Condition - Liquidity and ~~ELGs. Additionally, see~~Capital Resources - Forecasted Uses of Cash - Capital Expenditures" in "Item ~~1. Business - Environmental Matters"~~7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" in the Registrants' ~~2018~~2019 Form 10-K for ~~additional information.~~

~~EPA’s CCR Rule~~ ~~(PPL, LKE, LG&E and KU)~~

~~Over the next several years, LG&E and KU anticipate undertaking extensive measures, including significant~~information on projected environmental capital expenditures to comply with the provisions of the EPA's CCR Rule. Although LG&E and KU have identified compliance strategies and are finalizing closure plans and schedules as required by the CCR Rule, remaining regulatory uncertainties could substantially impact current plans. As a result of a judicial settlement, legislative amendments, and the EPA's review of the current program, the EPA is in the process of undertaking significant revisions to the CCR Rule. In July 2018, the EPA published certain amendments to the CCR Rule which include extending the deadline for commencement of closure of certain impoundments to October 2020. The EPA released additional proposed amendments to the rule on November 4, 2019, with further proposed amendments expected in the future. In August 2018, the D.C. Circuit Court of Appeals vacated and remanded portions of the CCR Rule, including provisions allowing unlined impoundments to continue operating and provisions exempting certain inactive impoundments from regulation. The exact impact of the judicial decision will be highly dependent on the EPA's rulemaking actions on remand and any subsequent legal challenges. LG&E and KU are evaluating the specific plan impacts of developments to date and will continue to monitor the EPA's ongoing regulatory proceedings.

~~In connection with the final CCR Rule, LG&E and KU recorded adjustments to existing AROs beginning in 2015 and continue to record adjustments as required.~~2020 through 2024. See Note ~~16 in this Form 10-Q and Note 19~~15 to the Financial Statements ~~in the Registrants’ 2018 Form 10-K~~ for ~~additional~~ information ~~on AROs. LG&E and KU continue to perform technical evaluations~~ related to their plans to close impoundments at all their generating plants. Although LG&E and KU believe their recorded liabilities appropriately reflect their obligations under current rules, changes to current compliance strategies as a resultthe impacts of ongoing regulatory proceedings or other developments could result in additional closure costs. It is not currently possible to determine the magnitude of any potential cost increases related to changes in compliance strategies or plans, and the timing of future cash outflows are indeterminable at this time. As rules are revised, technical evaluations are completed, and the timing and details of impoundment closures develop furtherCCRs on ~~a plant by-plant basis, LG&E and KU will update their cost estimates and record any changes as necessary to their ARO liability, which could be material. These costs are subject to rate recovery.~~AROs.

New Accounting Guidance (All Registrants)

See ~~Notes~~Note 2 ~~and 18~~ to the Financial Statements for a discussion of new accounting guidance ~~adopted and pending adoption.~~adopted.

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Application of Critical Accounting Policies (All Registrants)

Financial condition and results of operations are impacted by the methods, assumptions and estimates used in the application of critical accounting policies. The following table summarizes the accounting policies by Registrant that are particularly important to an understanding of the reported financial condition or results of operations, and require management to make estimates or other judgments of matters that are inherently uncertain. See "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" in the Registrants' ~~2018~~2019 Form 10-K for a discussion of each critical accounting policy.

PPL

Electric

LKE

LG&E

Defined Benefits

Income Taxes

Regulatory Assets and Liabilities

Price Risk Management

Goodwill Impairment

AROs

Revenue Recognition - Unbilled Revenue

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PPL Corporation

PPL Electric Utilities Corporation

LG&E and KU Energy LLC

Louisville Gas and Electric Company

Kentucky Utilities Company

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Reference is made to "Risk Management" in "Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations."

Item 4. Controls and Procedures

Although the COVID-19 pandemic prompted the Registrants to make certain procedural adjustments to accommodate an increased remote workforce, PPL’s accounting and reporting systems and functions were well prepared to perform necessary accounting and reporting activities as of March 31, 2020 and to maintain the effectiveness of its disclosure controls and procedures and internal control over financial reporting.

(a) Evaluation of disclosure controls and procedures.

The Registrants' principal executive officers and principal financial officers, based on their evaluation of the Registrants' disclosure controls and procedures (as defined in Rules 13a-15(e) or 15d-15(e) of the Securities Exchange Act of 1934) have concluded that, as of ~~September 30, 2019,~~March 31, 2020, the Registrants' disclosure controls and procedures are effective to ensure that material information relating to the Registrants and their consolidated subsidiaries is recorded, processed, summarized and reported within the time periods specified by the SEC's rules and forms, particularly during the period for which this quarterly report has been prepared. The ~~aforementioned~~ principal officers have concluded that the disclosure controls and procedures are also effective to ensure that information required to be disclosed in reports filed under the Exchange Act is accumulated and communicated to management, including the principal executive and principal financial officers, to allow for timely decisions regarding required disclosure.

(b) Change in internal controls over financial reporting.

The Registrants' principal executive officers and principal financial officers have concluded that there were no changes in the Registrants' internal controls over financial reporting during the Registrants' ~~third~~first fiscal quarter that have materially affected, or are reasonably likely to materially affect, the Registrants' internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

For information regarding legal, tax, regulatory, environmental or other administrative proceedings that became reportable events or were pending in the ~~third~~first quarter of ~~2019~~2020 see:

"Item 3. Legal Proceedings" in each Registrant's ~~2018~~2019 Form 10-K; and

Notes 6, 7 and 1110 to the Financial Statements.

Item 1A. Risk Factors

There have been no material changes in the Registrants' risk factors from those disclosed in "Item 1A. Risk Factors" of the Registrants' ~~2018~~2019 Form ~~10-K.~~10-K, except for the following:

The COVID-19 pandemic and resultant impact on business and economic conditions could negatively affect our business.

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or closures of businesses, schools and governmental agencies, and executive, legislative or regulatory actions to address health or other pandemic-related concerns.

Until COVID-19 is contained or an effective vaccine is identified and widely-available, the COVID-19 virus poses significant risks to the health and welfare of the Registrants’ customers, employees, contractors and suppliers, and to the conduct of their business. Mandates to stay at home, shelter in place, or quarantine and resulting lock-down or closures of non-essential businesses could reduce demand for electricity and gas, or cause shifts in demand between residential, commercial and industrial customers that could negatively impact the Registrants’ financial condition. Customers experiencing financial strain from unemployment, furloughs, or reduced work hours may not be able to pay their bills on a timely basis, which could negatively impact our liquidity. Continued economic disruption may further depress the GBP to U.S. dollar exchange rate and increase PPL's foreign exchange exposure. New or changing legislation or regulatory orders may unfavorably impact the Registrants or the utility industry generally.

All of these factors have the potential to materially and adversely affect the Registrants’ business and operations, especially if they remain in effect for a prolonged period of time. At this time, the Registrants’ cannot predict the extent to which these or other pandemic-related factors may affect their business, earnings or other financial results, as it depends on the duration and scope of the outbreak, the measures undertaken in response and other future developments, all of which are highly uncertain. In addition to the factors discussed above, investors should be aware that other COVID-19-related risks may emerge in the future and may prove to be significant. Investors should carefully consider the discussion of COVID-19 related items presented in this Quarterly Report and the risks presented in the Registrants’ Annual Report on Form 10-K for 2019, especially to the extent that the COVID-19 pandemic may exacerbate or increase those risks.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

The information below represents an update to "Item 1. Business - Environmental Matters - Water/Waste - Clean Water Act Jurisdiction" in the Registrants' 2019 Form 10-K.

Clean Water Act Jurisdiction

Environmental groups and others have claimed that discharges to groundwater from leaking CCR impoundments at power plants are subject to Clean Water Act permitting. A citizen suit raising such claims has been filed against KU with respect to the E.W. Brown plant, as discussed under “Legal Matters” - “E.W. Brown Environmental Claims” in Note 10 to the Financial Statements. On April 12, 2019, the EPA released regulatory clarification finding that Clean Water Act jurisdiction does not cover such discharges to groundwater. On January 23, 2020, the EPA announced a final rule modifying the jurisdictional scope of the Clean Water Act. The announced rule revises the definition of the "Waters of the United States," including a revision to exclude groundwater from the definition. In April 2020, the U.S. Supreme Court issued a ruling that Clean Water Act jurisdiction may apply to certain discharges to groundwater that result in the functional equivalent of a direct discharge to navigable waters. PPL, LKE, LG&E, and KU are unaware of any unpermitted releases from their facilities that are subject to Clean Water Act jurisdiction, but future guidance from the EPA and judicial rulings could potentially subject certain releases from CCR impoundments and landfills to additional permitting and remediation requirements, which could impose substantial costs. If any, associated costs are expected to be subject to rate recovery. PPL, LKE, LG&E and KU are unable to predict the outcome or financial impact of future regulatory proceedings and litigation.

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Item 6. Exhibits

The following Exhibits indicated by an asterisk preceding the Exhibit number are filed herewith. The balance of the Exhibits has heretofore been filed with the Commission and pursuant to Rule 12(b)-23 are incorporated herein by reference. Exhibits indicated by a [_] are filed or listed pursuant to Item 601(b)(10)(iii) of Regulation S-K.



*1(a)3(a)	-	~~Final Terms,~~Bylaws of PPL Corporation, effective as of March 23, 2020 (Exhibit 3(ii) to PPL Corporation Form 8-K Report (File No. 1-11459) dated ~~September 5, 2019, of Western Power Distribution (East Midlands) plc £250,000,000 Fixed Rate Notes due 2031 under the £4,000,000,000 Euro Medium Term Note Programme~~March 27, 2020)
4(a)	-	Supplemental Indenture ~~No. 21,~~No 17, dated as of ~~September~~April 3, 2020, to Indenture, dated as of November 1, ~~2019, of~~1997, among PPL ~~Electric Utilities~~Capital Funding, Inc., PPL Corporation toand The Bank of New York Mellon (as successor to JPMorgan Chase Bank, N.A. (formerly known as The Chase Manhattan Bank)), as Trustee (Exhibit ~~4(a)~~4(b) to PPL Corporation Form 8-K Report (File No. 1-11459) dated ~~September~~April 3, 2020)

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*10(a)	-	$100,000,000 Term Loan Credit Agreement, dated as of April 1, 2020, among PPL Capital Funding, Inc., as Borrower, PPL Corporation, as Guarantor, and Canadian Imperial Bank of Commerce, New York Branch, as Administrative Agent and Lender
*10(b)	-	$100,000,000 Term Loan Credit Agreement, dated as of April 1, 2020, among PPL Capital Funding, Inc., as Borrower, PPL Corporation, as Guarantor, and U.S. Bank National Association, as Administrative Agent and Lender
*10(c)	-	$200,000,000 Credit Agreement, dated as of March 27, 2020, among PPL Capital Funding, Inc., as Borrower, PPL Corporation, as Guarantor, and The Bank of Nova Scotia, as Administrative Agent and Lender
*10(d)	-	$50,000,000 Revolving Credit Agreement, dated as of March 12, 2020, among PPL Capital Funding, Inc., as Borrower, PPL Corporation, as Guarantor, and The Bank of Nova Scotia, as Administrative Agent and Lender
*10(e)	-	Amendment No. 6 ~~2019)~~to Revolving Credit Agreement, dated as of March 12, 2020, to the March 26, 2014 Existing Credit Agreement, between PPL Capital Funding, Inc., the Borrower, PPL Corporation, the Guarantor, and The Bank of Nova Scotia, as the Administrative Agent and as a Lender

Certifications pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, for the quarterly period ended September 30, 2019, filed by the following officers for the following companies:

*31(a)	-	PPL Corporation's principal executive officer
*31(b)	-	PPL Corporation's principal financial officer
*31(c)	-	PPL Electric Utilities Corporation's principal executive officer
*31(d)	-	PPL Electric Utilities Corporation's principal financial officer
*31(e)	-	LG&E and KU Energy LLC's principal executive officer
*31(f)	-	LG&E and KU Energy LLC's principal financial officer
*31(g)	-	Louisville Gas and Electric Company's principal executive officer
*31(h)	-	Louisville Gas and Electric Company's principal financial officer
*31(i)	-	Kentucky Utilities Company's principal executive officer
*31(j)	-	Kentucky Utilities Company's principal financial officer

Certifications pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, for the quarterly period ended September 30, 2019, furnished by the following officers for the following companies:

*32(a)	-	PPL Corporation's principal executive officer and principal financial officer
*32(b)	-	PPL Electric Utilities Corporation's principal executive officer and principal financial officer
*32(c)	-	LG&E and KU Energy LLC's principal executive officer and principal financial officer
*32(d)	-	Louisville Gas and Electric Company's principal executive officer and principal financial officer
*32(e)	-	Kentucky Utilities Company's principal executive officer and principal financial officer

101.INS	-	XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.SCH	-	XBRL Taxonomy Extension Schema
101.CAL	-	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	-	XBRL Taxonomy Extension Definition Linkbase
101.LAB	-	XBRL Taxonomy Extension Label Linkbase
101.PRE	-	XBRL Taxonomy Extension Presentation Linkbase
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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized. The signature for each undersigned company shall be deemed to relate only to matters having reference to such company or its subsidiaries.



		PPL Corporation
		(Registrant)



Date:	~~November 5, 2019~~May 8, 2020	/s/ Marlene C. Beers
		Marlene C. Beers Vice President and Controller
		(Principal Accounting Officer)



		PPL Electric Utilities Corporation
		(Registrant)



Date:	~~November 5, 2019~~May 8, 2020	/s/ Stephen K. Breininger
		Stephen K. Breininger Vice President-Finance and Regulatory Affairs and Controller
		(Principal Financial Officer and Principal Accounting Officer)



		LG&E and KU Energy LLC
		(Registrant)

		Louisville Gas and Electric Company
		(Registrant)

		Kentucky Utilities Company
		(Registrant)



Date:	~~November 5, 2019~~May 8, 2020	/s/ Kent W. Blake
		Kent W. Blake Chief Financial Officer
		(Principal Financial Officer and Principal Accounting Officer)

~~122~~102



	PPL		LKE		LG&E		KU
Right-of-Use Asset (a)	$	81	$	56	$	23	$	31
Lease Liability- Current (b)	23		18		9		9
Lease Liability- Noncurrent (c)	67		46		18		26



	Three Months
	PPL		LKE		LG&E		KU
Lease cost:
Operating lease cost	$	6	$	5	$	1	$	3
Short-term lease cost	2		1		—		1
Total lease cost	$	8	$	6	$	1	$	4

	Nine Months
	PPL		LKE		LG&E		KU
Lease cost:
Operating lease cost	$	21	$	17	$	7	$	9
Short-term lease cost	5		2		1		1
Total lease cost	$	26	$	19	$	8	$	10



	PPL		LKE		LG&E		KU
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	21	$	17	$	8	$	9
Right-of-use asset obtained in exchange for new operating lease liabilities	37		8		3		5



	Exposure at September 30, 2019			Expiration Date
PPL
Indemnifications related to the WPD Midlands acquisition			(a)
WPD indemnifications for entities in liquidation and sales of assets	$	10	(b)	2021
WPD guarantee of pension and other obligations of unconsolidated entities	77		(c)

PPL Electric
Guarantee of inventory value	26		(d)	2020

LKE
Indemnification of lease termination and other divestitures	200		(e)	2021

LG&E and KU
LG&E and KU obligation of shortfall related to OVEC			(f)



Derivatives Not Designated as	Location of Gain (Loss) Recognized in
Hedging Instruments	Income on Derivative	Three Months			Nine Months
Foreign currency contracts	Other income (expense) - net	$	44		$	56
Interest rate swaps	Interest expense	(1		)	(3		)
	Total	$	43		$	53
Derivatives Not Designated as	Location of Gain (Loss) Recognized as
Hedging Instruments	Regulatory Liabilities/Assets	Three Months			Nine Months
Interest rate swaps	Regulatory assets - noncurrent	$	(2	)	$	(5	)



	Three Months			Nine Months
Change in pre-tax income	$	15		$	(14	)
Valuation allowances (a)	2			4
Deferred tax impact of Kentucky state tax reform (b)	—			(9		)
Kentucky recycling credit, net of federal income tax expense (a)	—			(20		)
Other	(2		)	5
Total	$	15		$	(34	)



	Three Months			Nine Months
Distribution price (a)	$	18		$	20
Distribution volume	1			(3		)
PLR (b)	6			11
Transmission Formula Rate (c)	17			29
TCJA refund (d)	1			(6		)
Other	(1		)	1
Total	$	42		$	52



	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2019		2018			2019		2018
Net Income	$	118	$	111		$	333	$	334
Special Item, gain (loss), after-tax (a)	—		(5		)	—		(5		)



	2019 Three Months							2018 Three Months
	Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	590	$	—		$	590	$	548	$	—		$	548
Operating Expenses
Energy purchases	132		—			132		127		—			127
Other operation and maintenance	30		107			137		23		104			127
Depreciation	14		85			99		10		79			89
Taxes, other than income	27		2			29		25		2			27
Total Operating Expenses	203		194			397		185		185			370
Total	$	387	$	(194	)	$	193	$	363	$	(185	)	$	178

	2019 Nine Months							2018 Nine Months
	Adjusted Gross Margins		Other (a)			Operating Income (b)		Adjusted Gross Margins		Other (a)			Operating Income (b)
Operating Revenues	$	1,756	$	—		$	1,756	$	1,704	$	—		$	1,704
Operating Expenses
Energy purchases	413		—			413		403		—			403
Other operation and maintenance	92		325			417		92		327			419
Depreciation	36		254			290		26		236			262
Taxes, other than income	79		5			84		77		4			81
Total Operating Expenses	620		584			1,204		598		567			1,165
Total	$	1,136	$	(584	)	$	552	$	1,106	$	(567	)	$	539